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Home My WebLink About203-092Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 10/27/2025 InspectNo:susGDC250903205733 Well Pressures (psi): Date Inspected:9/2/2025 Inspector:Guy Cook If Verified, How?Other (specify in comments) Suspension Date:6/24/2021 #321-294 Tubing:0 IA:450 OA:150 Operator:Hilcorp Alaska, LLC Operator Rep:Steve Soroka Date AOGCC Notified:8/31/2025 Type of Inspection:Subsequent Well Name:MILNE PT UNIT S-32 Permit Number:2030920 Wellhead Condition Wellhead was in good condition. There is a wellhouse in place protecting the well from the elements. Well still connected to flowline and only isolated by the wing valve. Surrounding Surface Condition Good clean gravel pad with no signs of hydrocarbons. Condition of Cellar Water in the cellar. No signs of hydrocarbons. Comments Well location verified by well-site pad map Supervisor Comments Photos (10) attached Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Monday, October 27, 2025               2025-0902_Suspend_MPU_S-32_photos_gc Page 1 of 5 Suspended Well Inspection – MPU S-32 PTD 2030920 AOGCC Inspection Rpt # susGDC250903205733 Photos by AOGCC Inspector G. Cook 9/2/2025 Wellhouse Backside 2025-0902_Suspend_MPU_S-32_photos_gc Page 2 of 5 Tree and Power Fluid Piping 2025-0902_Suspend_MPU_S-32_photos_gc Page 3 of 5 SSV and Wing Valve Tree Cap Pressure Gauge (Tbg Pressure) 2025-0902_Suspend_MPU_S-32_photos_gc Page 4 of 5 IA Pressure Gauge OA Pressure Gauge 2025-0902_Suspend_MPU_S-32_photos_gc Page 5 of 5 Well Cellar Hilcorp Alaska, LLC David Haakinson, Milne Point Operations Manager 3800 Centerpoint Dr, Suite 400 Anchorage, Alaska 99503 08/19/2022 Chairman Jeremy Price Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Docket Number: OTH-22-025, Notice of Violation. Suspended Well Inspection Requirements. Milne Point Unit S-24 (PTD 203-038), S-32 (PTD 203-092), S-35 (PTD 203-143), Hilcorp Alaska, LLC. Dear Chairman Price, Please see below for information requested per Docket Number: OTH-22-025 on 08/17/2022 regarding suspended well inspection requirements for Milne Point Wells S-24 (PTD 203-038), S-32 (PTD 203-092), S-35 (PTD 203-143). Event Summary: Milne Point wells S-24 (suspended on 7/3/2021), S-32 (suspended on 6/24/2021), and S-35 (suspended on 9/19/2021) required inspections within 12 months after initial suspension. Upon review of our records on 07/25/2022, S-24 and S-32 were identified as being overdue for the initial inspection. On 07/26/2022, Hilcorp self-reported the issue and the AOGCC was notified of the delinquency and informed that the inspections would be submitted as soon as possible. The well inspections were completed and witnessed on 07/29/2022. Inspections were submitted for S-35 and S-24 on 08/05/2022 for record. S-32 inspection was submitted for record on 8/8/2022. Photos were taken during the inspection but lacked clarity needed to clearly identify well information. Investigation Details: Recent timeline of events leading to the late inspections: o 06/24/2022: S-32 (PTD 203-092) Initial suspended well inspection due. o 07/03/2022: S-24 (PTD 203-038) Initial suspended well inspection due. o 07/25/2022: Identified late inspections and communicated with the field to schedule inspection. o 07/26/2022: Communication to AOGCC that inspections would be late and the nature of the delay. o 07/29/2022: Field inspections of the suspended wells were completed. o 08/05/2022: S-24 (PTD 203-038) and S-35 (PTD 203-143) inspections submitted for record. o 08/08/2022: S-32 (PTD 203-092) inspection submitted for record. The suspended well inspection and renewal requirements are currently tracked within a manual entry spreadsheet monitored by the Well Integrity Engineer. As well statuses change and inspections are completed, the Well Integrity Engineer is responsible for updating the data accordingly. Periodic review of the data is completed to ensure compliance per 20 AAC 25.110(e). A review was conducted and identified two inspections not completed by their due date. Notification was sent to the field to conduct the inspections as soon as possible and a call was placed to AOGCC to self-report the late inspections. The inspections were completed and subsequently submitted for record. Photos were taken during the inspection and submitted as part of the record. During the process of taking and sending photos clarity of signage was not sufficient for all the well details. Hilcorp regrets this error. In MPU S-35’s case, the wellhouse was removed and placed nearby for gravel work at the time of photographs. Root cause of the incident: x Well Integrity Engineer failed to extract the correct information from the current data management system. By Samantha Carlisle at 3:48 pm, Aug 19, 2022 Contributing factors of the incident: x Manual entry and tracking of data with no automated alert in place to notify of upcoming and past-due obligations. Actions to prevent recurrence: x Migrate Milne Point Unit and Alaska Islands (Northstar, Endicott, and Point Thomson) teams to the Alaska Integrity Management System adopted by the Prudhoe Bay Unit which includes automated alerts for approaching and past-due obligations with notifications provided to personnel responsible for regulatory reporting. (Project began in May 2022 and targeted initial rollover by 1 September 2022. Full functionality planned to be in place by end of year 2022.) x Communicate to the company representatives photo requirements with regards to quality and content. x Communication to company representatives that well signage must be moved from wellhouse to wellhead in event of wellhouse removal. If you have any questions, please call me at 907-777-8343 or Jerimiah Galloway at 907-564-5005. Sincerely, David Haakinson Milne Point Operations Manager Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2022.08.19 11:29:28 -08'00' David Haakinson (3533) 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov August 17, 2022 CERTIFIED MAIL – RETURN RECEIPT REQUESTED 7018 0680 0002 2052 9723 Mr. David Haakinson MPU Operations Manager Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 Re: Docket Number: OTH-22-025 Notice of Violation Suspended Well Inspection Requirements Milne Point Unit S-24 (PTD 203-038) Milne Point Unit S-32 (PTD 203-092) Milne Point Unit S-35 (PTD 203-143) Dear Mr. Haakinson: Hilcorp Alaska, LLC (Hilcorp) conducted several Alaska Oil and Gas Conservation Commission (AOGCC) witnessed initial suspended well inspections on the Milne Point Unit (MPU) Spad wells listed above. Inspections occurred on July 29, 2022. All wells had at least one issue with the inspection or the inspection report: - MPU S-24: 20 AAC 25.110(e) requires the initial inspection of a suspended well to occur within 12 months of the date of suspension. The well was initially suspended on July 3, 2021, so the July 29th inspection was conducted 26 days late. The quality of photos submitted with the inspection report were too poor to assess whether the well sign meets the requirements of 20 AAC 25.040. - MPU S-32: 20 AAC 25.110(e) requires the initial inspection of a suspended well to occur within 12 months of the date of suspension. The well was initially suspended on June 24, 2021, so the July 29th inspection was more than a month overdue. The quality of photos submitted with the inspection report were too poor to assess whether the well sign meets the requirements of 20 AAC 25.040. - MPU S-35: Inspection report does not demonstrate that the well has the sign required by 20 AAC 25.040. Within 14 days of receipt of this letter, you are requested to provide the AOGCC with: Docket Number: OTH-22-025 Notice of Violation August 17, 2022 Page 2 of 2 1) a written description of why wells MPU S-24 and MPU S-32 were not inspected within 12 months of the date of initial suspension as required by 20 AAC 25.110(e) and what steps Hilcorp will take to ensure that initial suspended well inspections will occur within the time frame prescribed by the regulations. And, 2) legible photographs demonstrating that the three wells have signs that meet the requirements of 20 AAC 25.040. The AOGCC reserves the right to pursue addition enforcement action in connection with this Notice of Violation. Questions regarding this letter should be directed to Dave Roby at dave.roby@alaska.gov or (907)793-1232. Sincerely, Jeremy M. Price Chair, Commissioner cc: AOGCC Inspectors Jim Regg, AOGCC Phoebe Brooks, AOGCC Jeremy Price Digitally signed by Jeremy Price Date: 2022.08.17 13:52:12 -08'00' Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 08/30/2022 InspectNo:susAGE220802142337 Well Pressures (psi): Date Inspected:7/29/2022 Inspector:Adam Earl If Verified, How?Other (specify in comments) Suspension Date:6/24/2021 #321-294 Tubing:0 IA:400 OA:50 Operator:Hilcorp Alaska, LLC Operator Rep:Derek Weglin Date AOGCC Notified:7/27/2022 Type of Inspection:Initial Well Name:MILNE PT UNIT S-32 Permit Number:2030920 Wellhead Condition Wellhead in good working condition. Wellhouse left on. Surrounding Surface Condition good. free of any sheens or trash Condition of Cellar water in cellar do to recent heavy rain ,water level is below valves, to be sucked out soon. Comments verified by pad map Supervisor Comments Photo (1) attached Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Tuesday, August 30, 2022 9 9 9 9 9 9 9 9 9 2022-0729_Suspend_MPU_S-32_photo_ae Page 1 of 1 Suspended Well Inspection – MPU S-32 PTD 2030920 AOGCC Inspect # susAGE220802142337 Photo by AOGCC Inspector A. Earl 7/29/2022 By Anne Prysunka at 1:53 pm, Aug 08, 2022 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10,679 feet N/A feet true vertical 3,876 feet N/A feet Effective Depth measured 7,266 feet feet true vertical 3,807 feet feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 4-1/2"12.6# / L-80 / IBT-M 7,330' 3,831' Tubing (size, grade, measured and true vertical depth)3-1/2"9.2# / L-80 / TC-II 7,398' 3,855' Packers and SSSV (type, measured and true vertical depth)N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name:Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: 4,790psi 6,590psi10,676' 4" 10,676' 3,876' Hilcorp Alaska LLC measured true vertical Packer 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 7,342' MD / 3,835' TVD 375 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 0 Casing Pressure WINJ WAG 0 Water-Bbl MD 110' 2,398'3,173' TVD Gas-Mcf 7-5/8" x 4-1/2" Premier Packer and N/A 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data N/A0 measured 110' Oil-Bbl MILNE PT UNIT S-32 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 203-092 50-029-23157-00-00 Plugs ADL0380109 5. Permit to Drill Number: MILNE POINT / SCHRADER BLUFF OIL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 321-294 N/A Authorized Signature with date: David Haakinson dhaakinson@hilcorp.com 0 N/A Conductor Size Junk Length Surface 20" 10-3/4" 7,910psi Senior Engineer: Senior Res. Engineer: Collapse 520psi 2,470psi Burst 1,530psi 5,210psi Liner N/A 777-8343 2. Operator Name 110' 3,173' measured Casing Tubing Pressure 0 Intermediate 7-5/8"7,543' 7,543' 3,900' 7,342 3,835 6,890psi L G Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Meredith Guhl at 9:02 am, Jul 21, 2021 Chad Helgeson (1517) 2021.07.21 08:43:01 - 08'00' DSR-7/21/21 SFD 7/21/2021MGR23JUL21 RBDMS HEW 7/22/2021 Well Name Rig API Number Well Permit Number Start Date End Date MP S-32 Coiled Tubing 50-029-23157-00-00 203-092 6/21/2021 6/24/2021 6/23/2021 - Wednesday RIH with 2" cementing ball drop nozzle. Tag at 10,280'. Attempt to get returns to surface and WHP goes to 0 psi, no returns to surface. Call out for more diesel. Load backside with diesel to get positive wellhead pressure. Load coil with diesel. RIH to 10,250' and circulate to return tanks and confirm 1:1 returns. Pump 40 bbls of 15.8# cement, laying in 1:1 with 1 bbl of cement above nozzle from 10,250' to 7600'. Close choke and squeeze away 7 bbls of cement. POOH to 7100' then RIH and contaminate to 7600' with PowerVis. POOH pumping diesel and taking returns to open top at 1:1. Well freeze protected. Coil at surface. Secure well. LDFN. 6/24/2021 - Thursday MU 2" JSN and RIH. AOGCC representative Guy Cook on location to witness TOC tag and MIT. Tag TOC at 7,266' ctmd. Perform MIT - Passed. Start: 1840/451/49. 15 min: 1757/450/51. 30 min: 1732/451/52. 6/18/2021 - Friday Pressure test surface lines 250/2500 psi. CMIT-TxIA to 1500 psi Failed. Pumped 3 bbls diesel down IA (TBG tracked). Monitored T/IA pressures for 5 min, TBG lost 420 psi and IA lost 340 psi in 5 min. Established LLR of .3 bpm @ 1500 psi with 2 bbls diesel. Monitored pressures for 10 min. Hilcorp Alaska, LLC Weekly Operations Summary MIRU SLB coiled tubing unit. RIH with 1.75" slim DJN for cleanout. Well has T x IA communication. Dry tag at 7638' ctmd. Start pumping slick water/gel sweeps with N2 taking returns to surface. Take ~ 150' bites and sweep back uphole, take occasional bites up into tubing tail. Start locking up ~ 9900'. Pick uphole and RIH cleaning until reach lock up at 10,052'. POOH chasing returns to surface. Coil at surface. LDFN. 6/22/2021 - Tuesday _____________________________________________________________________________________ Revised By: DH 7/20/2021 SCHEMATIC Milne Point Unit Well: MPU S-32 Last Completed: 6/30/2003 PTD: 203-092 TD =10,679’(MD) / TD =3,876’(TVD) 20” Orig. KB Elev. = 72.00’ / Orig. GL Elev.= 30.35’ Doyon 14 7-5/8” 12 13 & 14 1 Suspected casing leak @ 4,850’ PBTD = 7,266’ (MD) / PBTD = 3,807’(TVD) 10-3/4 ” 3 6 7 11 10 2 5 4 8 9 TOC @ ~7,266’ ctmd on 6/24/21 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 92 / H-40 N/A Surface 110' 0.355 10-3/4" Surface 45.5 / L-80 / Btc 9.950 Surface 3,173’ 0.0962 7-5/8” Intermediate 29.7 / L-80 / BTC-M 6.875 Surface 7,543’ 0.0459 4” Production Liner 9.5 & 12.6/ L-80/ IBT 3.548 7,452’ 10,676’ 0.0122 TUBING DETAIL 4-1/2” Tubing 12.6/ L-80 / IBT-M 3.958 Surface 7,330’ 0.0152 3-1/2” Tubing 9.2 / L-80 / TC-II 2.992 7,330 7,398’ 0.0087 JEWELRY DETAIL No Depth Item 1 2,392’ Camco 4-1/2” x 1” Side pocket KGB-2 GLM w/ DCK-2 Valve, BK Latch w/ Dummy 2 7,282’ Phoenix Discharge Pressure Gauge , BTC Pin 3 7,293’ 4.5” HES ‘XD’ Dura Sliding Sleeve – 3.813” ID, Opens Down w/ Rev. Circ Jet Pump 4 7,316’ Phoenix Jet Pump Sensor 5 7,330’ X-Over: 4-1/2”TC-2 Box x 3-1/2” TC-2 Pin 6 7,332’ OTIS X-Nipple – 2.813” Profile 7 7,341’ X-Over: 3-1/2”TC-2 Box x 4-1/2” TC-2 Pin 8 7,342’ Baker 7-5/8” x 4-1/2” Premier Packer 9 7,349’ X-Over: 4-1/2”TC-2 Box x 3-1/2” TC-2 Pin 10 7,392’ HES3-1/2” XN-Nipple w/ 2.750 No-go w/ RHC Plug 11 7,397’ WLEG – Bottom @ 7,398 (3,855 TVD) 12 7,452’ Baker Tie Back Sleeve 13 7,459’ Baker ZXP Liner Top Packer 14 7,465’ Baker 7-5/8” x 5-1/2” HMC Liner Hanger OPEN HOLE / CEMENT DETAIL 20" 260sx of Arctic Set (Approx) in 42” Hole 10-3/4” 595sx PF “L”, 275sx Class ‘G’ in a 13-1/2” Hole 7-5/8” 425sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 370’ MD Hole Angle Passes 50 Deg. @ 2,300’ Max Hole Angle in Tubing = 72 deg. 68 Deg. @ Sliding Sleeve (3,817 TVD) WELLHEAD Tree 4-1/16” – 5M FMC Wellhead 11” x 4.5” 5M Gen. 6 w/ 4.5” TC-II T&B Tubing Hanger CIW “H” BPV Profile GENERAL WELL INFO API: 50-029-23157-00-00 Drilled and Completed by Doyon 14 - 6/30/2003 Added Perforations to Screens – 6/6/2008 NOTE: 5/19/2011 – No injectivity into formation post CTU clean-out to 7,475’. Pressured to 3,776psi. 79 Jts 4” Screened Liner & Blanks 7,723’ to 10,630’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Schrader 10,200’ 10,300’ 3,904’ 3,901’ 100 6/6/2008 Open Schrader Sands MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 1- 7 7cr fly 121 P.I. Supervisor �1 FROM: Guy Cook Petroleum Inspector Section: 12 Township: Drilling Rig: n/a Rig Elevation: Operator Rep: Bradley Gathman Casing/Tubing Data (depths are MD): Conductor: 20" 0. D. Shoe@ Surface: 10 3/4" 0. D. Shoe@ Intermediate: 7 5/8" 0. D. Shoe@ Production: Feet 0. D. Shoe@ Liner: 4" 0. D. Shoe@ Tubing: 4.5" x 3.5" ' 0. D. Tail@ Plugging Data: Test Data: Remarks: 12N n/a DATE: June 24, 2021 SUBJECT: Plug Verification MPU S-32 Hilcorp Alaska LLC PTD 2030920; Sundry 321-294 Range: 10E Total Depth: 10679 ft MD Suspend: X 110 Feet 3173 Feet 7543 Feet Feet 10676 Feet 7398 - Feet Meridian: Umiat ' Lease No.: ADL0380109 P&A: Casing Removal: Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Tbg Cut@ Feet Type Plug Founded on Depth Btm) Depth (To) MW Above Verified Perforation Bottom 10280 ft MD 7266 ft MD 15.8 ppg T C.T. Tag " 51 52 Initial 15 min 30 min 45 min Result Tubing 1840 1757 1732 IA 451 450 451 P OA 49 51 52 RIH with coil tubing (CT) to 7266 ft MD and tagged. Put 10,000 pounds down -force on the cement with no movement. Repeated tag with the same down -force with no change. The approved sundry did not include a pressure test after the tag-, Hilcorp believed there was TxIA communication that would have to be addressed before pressure testing. After watching the pressures as the CT was run in the hole for the tag, I was certain they did not have communication. I contacted Mel Rixse (AOGCC) and he agreed we should do the test. Pressured up tubing to 1840 psi and held 30 minutes for a passing test. Attachments: None rev. 11-28-18 2021-0624_Plug_Verification_M PU_S-32_gc 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 10,679'N/A Casing Collapse Conductor 520psi Surface 2,090psi Intermediate 4,790psi Liner 6,590psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name: Operations Manager Contact Email:Abhijeet.Tambe@hilcorp.com Contact Phone: 777-8485 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Tubing Grade: Tubing MD (ft): Abhijeet Tambe COMMISSION USE ONLY Authorized Name: Authorized Signature: 6/25/2021 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0380109 203-092 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23157-00-00 Hilcorp Alaska LLC Length Size 3,876' 10,679' 3,876' 1,685 N/A MILNE POINT / SCHRADER BLUFF OIL 110' 110' 9.2# / L-80 / TC-II TVD Burst 7,398 MD 1,530psi 7,910psi Tubing Size: 3,580psi 6,890psi 2,398' 3,900' 3,876' 3,173' 7,543' 10,676' 110' 20" 10-3/4" 7-5/8" 3,173' 4"10,676' 7,543' Perforation Depth MD (ft): See Schematic See Schematic Perforation Depth TVD (ft): 4-1/2" 12.6# / L-80 / TC-II 7,330 MILNE PT UNIT S-32 C.O. 477.05 7-5/8" x 4-1/2" Premier Packer and N/A 7,342' (MD) / 3,835' & N/A Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 3-1/2" ory Statu Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. Chad Helgeson (1517) 2021.06.14 16:50:58 - 08'00' By Samantha Carlisle at 8:06 am, Jun 15, 2021 321-294 DSR-6/15/21SFD 6/15/2021 AOGCC to witness CT tag and pressure test of reservoir abandonment plug. Pressure test to 1500 psi. 10-404 MGR18JUN21 dts 6/18/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.06.18 09:32:23 -08'00' RBDMS HEW 6/21/2021 Well Suspension Well: MPU S-32 Date: 06/14/2021 Well Name:MPU S-32 API Number:50-029-23157-00-00 Current Status:Oil Well (Shut In)Pad:Milne Point S-Pad Estimated Start Date:June 25, 2021 Rig:CTU #6 Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:203-0920 First Call Engineer:Abhijeet Tambe (907) 777-8485 (O) (907) 331-9184 (M) Second Call Engineer:David Gorm (907) 777-8333 (O) (505) 215-2819 (M) AFE Number:Job Type:Reservoir Suspension Current Bottom Hole Pressure: 1,872 psi @ 4,000’ TVD (Offset injector S-14 BHP, EMW = 9.0 ppg) Maximum Expected BHP:1,872 psi @ 4,000’ TVD (EMW = 9 ppg) MPSP:1,685 psi (0.1 psi/ft gas gradient) Brief Well Summary MPS-32 was drilled and completed in June 2003 as a jet-pumped single-lateral Schrader Bluff N-sand producer. Original completion design included 4” Baker medium Excluder sand screens. However, in 2008 a 100’ section of the sand screen was perforated from 10,200’-10,300’ MD to increase the wells PI for suspicion of fines plugging across the screens. During a cleanout in 2008, CT could not get past 10,335’ MD. In 2011, due to the unsuccessful attempt to pull the Jet pump with SL, coil pulled the jet pump and progressed to clean out below the jet pump. CT was only able to clean out to 7,475’ MD (75’ below tubing tail) before running out of fluids. An injectivity test was performed but only succeeded in pressuring up the tubing. A regulatory required MIT-IA failed in December 2011 prior to N2 FCO. A casing leak (IA x Formation) was identified. An Archer TecWell LDL was performed in June 2013 to determine the location of the casing leak in preparation for a casing repair. The LDL was unable to pick up the 0.4 BPM leak, however, temperature logs strongly indicated leak stemming from ~4,850’ MD. The well has been shut-in since 2013. Notes Regarding Wellbore Condition x CMIT-IA failed on 01/18/2016. x MIT-T passed to 2,000 psi on 12/25/2011. x Suspected casing leak at ~4,850’ MD. Objective: To suspend entire horizontal lateral with cement. The planned redevelopment pattern for the S-Pad Schrader Bluff requires this N-sand lateral to be suspended prior to drilling future well MPS-46i due to crossing the planned injector to ensure proper reservoir flooding. MPS-32 must be suspended to 9,500’ MD (Past new injector S-46) to help minimize potential communication (MBE’s). The casing leak at approximately 4,850’ MD will also be cemented. Slickline Procedure: 1. MIRU SL. 2. RIH and pull RHC plug from XN nipple at 7,392’ MD. POOH. 3. MU shifting tool. 4. RIH and close HES “XD” Dura sliding sleeve @ 7,293’ MD. 5. D&T, note tag depth and type of fill for CT FCO. Well Suspension Well: MPU S-32 Date: 06/14/2021 Coiled Tubing Procedure (Approval Required to Proceed): 6. MIRU Coiled Tubing Unit and spot ancillary equipment. Fill source tank w/1% KCl. 7. Pressure test BOPE to 3,500 psi Hi 250 Low, 10 min Hi, 5 min Low each test. a. If within the standard 7-day test BOPE test period for Milne Point, a full body test and function test of the rams is sufficient. b. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks. 8. RIH with 2” CT and JSN to the top of the 4” screens at 7,725’. Cleanout the 4”, 9.5# liner to TD at 10,630’ with 1% KCl and gel sweeps. a. A FCO in 2011 made it to 7,475’ MD. b.To minimize potential communication with planned injector (MPS-46), minimum target depth to clean out is 9,500’ MD (2,000’ into the liner). c.Contingency: If unable to wash down with nozzle, RIH w/motor & mill and extended reach cleanout BHA and cleanout to PBTD using 1% KCl w/liquid foamer and mix with Nitrogen. Utilize defoamer for returns in Kill Tank. (See Nitrogen procedure and flow diagram). 9. POOH. 10. MU ball drop cementing nozzle and RIH to 10,630’ or deepest depth reached during FCO. 11. RU cementers. 12. Mix and pump 50 bbls of 15.8 ppg Class G cement down the coil tubing taking returns up the 4” tubing. Use freshwater spacers as needed around the cement. a. 4” liner vol: 0.0122 x (10,630’ – 7,452’) = ~39 bbls 13. Allow ~1 bbl of cement around the cementing nozzle and lay the rest of the cement in at 1:1. Pause at 7,480’ MD (top of screens) and attempt to squeeze ±5 bbls cement until a bump in pressure is observed. 14. PU to 7,450’ and attempt to squeeze away ±5 bbls of cement. (volume dependent on cement volume squeezed in step 13) 15. Swap to contaminate and RIH to circulate to 7,450’ MD (planned TOC). 16. POOH and circulate coil tubing clean as needed. a. Freeze protect well on way out of hole. 17. Wait on cement to gain 1,000 psi compressive strength. 18. Pressure test the cement to 1,500 psi for 30 minutes (charted). a.Notify AOGCC 24 hours in advance to witness pressure test. b. If the pressure test of the cement plug fails, contact the Operations Engineer to discuss pumping additional cement. 19. Freeze protect well. POOH. 20. RD CT unit. Slickline Procedure: 21. MIRU the slickline unit and support equipment. 22. RIH with drive down bailer, tag TOC (note tag depth on report) and POOH. 23. Open sliding sleeve at 7,293’. Using diesel establish circulation, but do not pump all freeze protect fluid out. a. If sleeve does not open. PU, MU and RIH with tubing punch to just above the Otis X nipple at 7,332’. 24. PU to ~7,310’ (first full joint above the packer), punch the tubing and POOH. 25. RDMO the slickline unit. and TAG. State to witness tag of TOC with coiled tubing. Well Suspension Well: MPU S-32 Date: 06/14/2021 Cementing Procedure: 26. MIRU cementing unit and support equipment. 27. Line up to circulate down the tubing taking return up the IA to tanks. PT lines to 2,500 psi. 28. Establish circulation and pump 40 bbls of fresh water to recover the diesel on the IA. 29. Pump ±30 bbl spacer followed by ±200 bbls of 15.8 ppg class G cement. Take returns off the IA and tubing as required to get a balanced cement plug. Maintain 1,000 psi on IA to prevent cement U-tube on the back side. a. Estimated TOC in IA ~2,600’ MD (500’ inside 10-3/4” surface casing) 30. After pumping ~200 bbls of cement down the tubing, switch to displacement. a. Cement volume from tbg punches to ~2,600’ = ~125 bbls b. Cement volume in tubing: ~70 bbls 31. Flush all surface line with fresh water to tanks. 32. RDMO the cementing unit. Slickline Procedure: 33. Notify AOGCC 24 hrs in advance of tag of TOC and PT 34. MIRU SL unit and support equipment. 35. RIH and tag TOC (note tag depth on report) and POOH. 36. CMIT – TxIA to 1,500 psi for 30 mins (charted). 37. RDMO. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. Coiled Tubing BOPE schematic 4. N2 Procedure & Flow Diagram for contingency (if necessary) No state witness required. _____________________________________________________________________________________ Revised By: DH 6/14/2021 SCHEMATIC Milne Point Unit Well: MPU S-32 Last Completed: 6/30/2003 PTD: 203-092 TD = 10,679’ (MD) / TD =3,876’(TVD) 20” Orig. KB Elev. = 72.00’ / Orig. GL Elev.= 30.35’ Doyon 14 7-5/8” 12 13 & 14 1 Suspected casing leak @ 4,850’ 10-3/4” 3 6 7 11 10 2 5 4 8 9 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 92 / H-40 N/A Surface 110' 0.355 10-3/4" Surface 45.5 / L-80 / Btc 9.950 Surface 3,173’ 0.0962 7-5/8” Intermediate 29.7 / L-80 / BTC-M 6.875 Surface 7,543’ 0.0459 4” Production Liner 9.5 & 12.6/ L-80/ IBT 3.548 7,452’ 10,676’ 0.0122 TUBING DETAIL 4-1/2” Tubing 12.6/ L-80 / IBT-M 3.958 Surface 7,330’ 0.0152 3-1/2” Tubing 9.2 / L-80 / TC-II 2.992 7,330 7,398’ 0.0087 JEWELRY DETAIL No Depth Item 1 2,392’ Camco 4-1/2” x 1” Side pocket KGB-2 GLM w/ BK Latch w/ Dummy 2 7,282’ Phoenix Discharge Pressure Gauge, BTC Pin 3 7,293’ 4.5” HES ‘XD’ Dura Sliding Sleeve – 3.813” ID, Opens Down w/ Rev. Circ Jet Pump 4 7,316’ Phoenix Jet Pump Sensor 5 7,330’ X-Over: 4-1/2”TC-2 Box x 3-1/2” TC-2 Pin 6 7,332’ OTIS X-Nipple –2.813” Profile 7 7,341’ X-Over: 3-1/2”TC-2 Box x 4-1/2” TC-2 Pin 8 7,342’ Baker 7-5/8” x 4-1/2” Premier Packer 9 7,349’ X-Over: 4-1/2”TC-2 Box x 3-1/2” TC-2 Pin 10 7,392’ HES3-1/2” XN-Nipple w/2.750 No-go w/ RHC Plug 11 7,397’ WLEG –Bottom @ 7,398 (3,855 TVD) 12 7,452’ Baker Tie Back Sleeve 13 7,459’ Baker ZXP Liner Top Packer 14 7,465’ Baker 7-5/8” x 5-1/2” HMC Liner Hanger OPEN HOLE / CEMENT DETAIL 20" 260sx of Arctic Set (Approx) in 42” Hole 10-3/4” 595sx PF “L”, 275sx Class ‘G’ in a 13-1/2” Hole 7-5/8” 425sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 370’ MD Hole Angle Passes 50 Deg. @ 2,300’ Max Hole Angle in Tubing = 72 deg. 68 Deg. @ Sliding Sleeve (3,817 TVD) WELLHEAD Tree 4-1/16” – 5M FMC Wellhead 11” x 4.5” 5M Gen. 6 w/ 4.5” TC-II T&B Tubing Hanger CIW “H” BPV Profile GENERAL WELL INFO API: 50-029-23157-00-00 Drilled and Completed by Doyon 14 - 6/30/2003 Added Perforations to Screens – 6/6/2008 NOTE: 5/19/2011 – No injectivity into formation post CTU clean-out to 7,475’. Pressured to 3,776psi. 79 Jts 4” Screened Liner & Blanks 7,723’ to 10,630’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Schrader 10,200’ 10,300’ 3,904’ 3,901’ 100 6/6/2008 Open Schrader Sands _____________________________________________________________________________________ Revised By: DH 6/14/2021 PROPOSED Milne Point Unit Well: MPU S-32 Last Completed: 6/30/2003 PTD: 203-092 TD =10,679’(MD) / TD =3,876’(TVD) 20” Orig. KB Elev. = 72.00’ / Orig. GL Elev.= 30.35’ Doyon 14 7-5/8” 12 13 & 14 Proposed tubing punch at 7,310’ 1 Suspected casing leak @ 4,850’ Proposed TOC @ ~2,600’ 10-3/4” 3 6 7 11 10 2 5 4 8 9 Proposed TOC @ ~3,100’ CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 92 / H-40 N/A Surface 110' 0.355 10-3/4" Surface 45.5 / L-80 / Btc 9.950 Surface 3,173’ 0.0962 7-5/8” Intermediate 29.7 / L-80 / BTC-M 6.875 Surface 7,543’ 0.0459 4” Production Liner 9.5 & 12.6/ L-80/ IBT 3.548 7,452’ 10,676’ 0.0122 TUBING DETAIL 4-1/2” Tubing 12.6/ L-80 / IBT-M 3.958 Surface 7,330’ 0.0152 3-1/2” Tubing 9.2 / L-80 / TC-II 2.992 7,330 7,398’ 0.0087 JEWELRY DETAIL No Depth Item 1 2,392’ Camco 4-1/2” x 1” Side pocket KGB-2 GLM w/ DCK-2 Valve, BK Latch w/ Dummy 2 7,282’ Phoenix Discharge Pressure Gauge , BTC Pin 3 7,293’ 4.5” HES ‘XD’ Dura Sliding Sleeve – 3.813” ID, Opens Down w/ Rev. Circ Jet Pump 4 7,316’ Phoenix Jet Pump Sensor 5 7,330’ X-Over: 4-1/2”TC-2 Box x 3-1/2” TC-2 Pin 6 7,332’ OTIS X-Nipple –2.813” Profile 7 7,341’ X-Over: 3-1/2”TC-2 Box x 4-1/2” TC-2 Pin 8 7,342’ Baker 7-5/8” x 4-1/2” Premier Packer 9 7,349’ X-Over: 4-1/2”TC-2 Box x 3-1/2” TC-2 Pin 10 7,392’ HES3-1/2” XN-Nipple w/2.750 No-go w/ RHC Plug 11 7,397’ WLEG –Bottom @ 7,398 (3,855 TVD) 12 7,452’ Baker Tie Back Sleeve 13 7,459’ Baker ZXP Liner Top Packer 14 7,465’ Baker 7-5/8” x 5-1/2” HMC Liner Hanger OPEN HOLE / CEMENT DETAIL 20" 260sx of Arctic Set (Approx) in 42” Hole 10-3/4” 595sx PF “L”, 275sx Class ‘G’ in a 13-1/2” Hole 7-5/8” 425sx Class “G” in 9-7/8” Hole WELL INCLINATION DETAIL KOP @ 370’ MD Hole Angle Passes 50 Deg. @ 2,300’ Max Hole Angle in Tubing = 72 deg. 68 Deg. @ Sliding Sleeve (3,817 TVD) WELLHEAD Tree 4-1/16” – 5M FMC Wellhead 11” x 4.5” 5M Gen. 6 w/ 4.5” TC-II T&B Tubing Hanger CIW “H” BPV Profile GENERAL WELL INFO API: 50-029-23157-00-00 Drilled and Completed by Doyon 14 - 6/30/2003 Added Perforations to Screens – 6/6/2008 NOTE: 5/19/2011 – No injectivity into formation post CTU clean-out to 7,475’. Pressured to 3,776psi. 79 Jts 4” Screened Liner & Blanks 7,723’ to 10,630’ PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Date Status Schrader 10,200’ 10,300’ 3,904’ 3,901’ 100 6/6/2008 Open Schrader Sands Reservoir Abandonment Well: MPU S-32 06/04/2021 COIL BOPE Valve, Swab, WKM-M, 4 1/16 5M FE Valve, Upper Master, Baker, 4 1/16 5M FE, w/ Hydraulic END 2-02 30 X 20 X 13д X 9з X 7 X 4 ½ Coil Tubing BOP Valve, Lower Master, WKM-M, 4 1/16 5M FE Blind/Shear Blind/Shear Lubricator to injection head 4 1/16 10M Slip Slip Blind/Shear Blind/Shear Pipe Pipe Manual Gate 2 1/8 5M 2д" Single Stripper Crossover spool 4 1/16 10M X 4 1/16 5M Manual Gate 2 1/8 5M Tubing Adapter, 4 1/16 5M Pump-In Sub 4 1/16 5M 1502 Union STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. Coil Tubing Unit Fluid Flow Diagram Cleanout w/ Nitrogen & Foam Updated 9/22/16 LEGEND: Fluids Pumped Fluids Returned Valve Open Valve Closed Gate Valve Ball Valve Butterfly Valve Lo Torq Valve Check Valve Manual Choke Pressure Gauge 500 BBL KILL TANK Choke Manifold P 400 BBL UPRIGHT P Open VBR BLIND COIL PUMP 400 BBL UPRIGHT Open Closed Open Open Open Open Open Open Open P SW or KCL W/ FOAMER OR FRIC TION REDUCER 50 BBL FREEZE PROTECT TANK SW or KCL W/ FOAMER OR FRIC TION REDUCER To Flowline NITROGEN PUMP & TANK P COIL UNIT WITH 1.5” to 2.0” COIL 400 BBL UPRIGHT SEAWATER W/ DEFOAMER TRIPLEX /Image ~ .bject Well History File C\. )er Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. aD 3 - Oç¡ c:2 Well History File Identifier D Two-sided 111111111I1111 11111 Organizing (done) D Rescan Needed 1- RESCAN DIGITAL DATA ~skettes, No.3 D Other, NolType: OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner o Color Items: o Greyscale Items: o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: D Logs of various kinds: Scanning Preparation BY: Hele~ I D Other:: Date: ~ :J.. 4 os Isl m P 1 Date: '6, ~lf Os Isl .. ~ -0 X 30 = 30 + á-~ = TOT~L. PAGES sg (Cou~ces not jHclude cover shev~ A .0 Date1j ~Lf Ds 151 V y ~ I /. 1 . NOTES: BY: Helen ~ Project Proofing BY: Helen~ Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES NO Heien~ Date: t;3 ~ y. OS Isl MP If NO in stage 1 page(s) discrepancies were found: BY: Stage 1 BY: BY: Helen Maria YES NO Date: 151 .11 11111111111 11111 11I1111111111111111 1 Date: Isl Quality Checked 111111111111111111I Helen Maria Scanning is complete at this point unless rescanning is required. ReScanned Comments about this file: • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 Si-ANNEDFFB 9, 4 re-V1' Mr. Tom Maunder o203 — 1 Alaska Oil and Gas Conservation Commission c — 3 �-- 333 West 7 Avenue rit Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPS -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPS -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • 0 BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPS -Pad 10/11/2011 Corrosion • Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft gal MPS-01A 2070340 50029231410100 0.25 NA 0.25 NA 5.1 9/6/2011 MPS-02 2031270 50029231690000 2.5 NA 2.5 NA 23.8 7/302011 MPS-03 2021460 50029231050000 Open Flutes - Treated MPS-04 2030520 50029231480000 1.7 NA 1.7 NA 17.0 7/30/2011 MPS-05 2021370 50029231000000 , Open Flutes - Treated MPS-06 2031090 50029231630000 1.7 NA 1.7 NA 17.0 7/30/2011 MPS-07 2020720 50029230790000 1 NA 1 NA 13.6 11132009 MPS -08 2031230 50029231680000 1.3 NA 1.3 NA 10.2 7/30/2011 MPS-09 2020200 50029230670000 0.5 NA 0.5 NA 5.1 11/3/2009 MPS -10A 2051250 50029231520100 1.3 NA 1.3 NA 11.9 7/29/2011 MPS -11 2021130 50029230920000 1 NA 1 NA 10.2 7/29/2011 MPS-12 2030230 50029231390000 0.6 NA 0.6 NA 6.8 7/29/2011 MPS -13 2021240 50029230930000 1 NA 1 NA 11.9 11/32009 MPS-14 2031040 50029231620000 1.8 NA 1.8 NA 22.1 7/29/2011 MPS -15 2012450 50029230610000 9.6 NA 9.6 NA 88.4 7/31/2011 MPS -16 2030650 50029231510000 1.2 NA 1.2 NA 10.2 7292011 MPS -17 2021730 50029231150000 Open Flutes - Treated MPS -18 2022420 50029231330000 1.3 NA 1.3 NA 11.9 7/29/2011 MPS -19A 2022330 50029231210100 1.8 NA 1.8 NA 23.8 7/29/2011 MPS -20 2022410 50029231320000 1.3 NA 1.3 NA 11.9 7/29/2011 MPS -21 2020090 50029230650000 1.8 NA 1.8 NA 22.1 11/3/2009 MPS -22 2031470 50029231760000 9.1 NA 9.1 NA 83.3 728/2011 MPS-23 2021320 50029230980000 Open Flutes - Treated MPS-24 2030380 50029231420000 1.3 NA 1.3 NA 10.2 7/28/2011 MPS -25 2021030 50029230890000 Open Flutes - Treated MPS -26 2030610 50029231500000 1 NA 1 NA 8.5 7/28/2011 MPS -27 2020850 50029230840000 0.9 NA 0.9 NA 8.5 7/28/2011 MPS -28 2030940 50029231580000 1.1 NA 1.1 NA 11.9 7/28/2011 MPS -29 2021950 50029231190000 Open Flutes - Treated MPS-30 2022360 50029231310000 1.2 NA 1.2 NA 11.9 7/28/2011 MPS -31 2020140 50029230660000 Open Flutes - Treated - • - 'P" MPS-32 2030920 50029231570000 0.8 NA 0.8 NA 6.8 7/28/2011 MPS-33A 2061720 50029231230100 1 NA 1 NA 6.8 7/28/2011 MPS-34 2031300 50029231710000 6 NA 6 NA 49.3 7/28/2011 MPS-35 2031430 50029231750000 1.2 NA 1.2 NA 11.9 7/28/2011 MPS-37 2070520 50029233550000 13.9 Need top job NA MPS-39 2081830 50029234050000 0.7 NA 0.7 NA 4.3 8/18/2011 MPS-41A 2081610 50029234010100 Sealed NA NA NA NA NA MPS-43 2081760 50029234040000 Dust Cover NA NA NA 6.8 10/11/2011 MPS -90 2051350 50029232760000 0.6 NA 0.6 NA 3.4 9/6/2011 MPSB-04 500299990799 0.6 NA 0.6 NA 3.4 7/30/2011 -~~~~' STATE OF ALASKA /~O ALA~OIL AND GAS CONSERVATION COMIv~ION REPORT OF SUNDRY WELL OPERATIONS ~~~~ ~~ 8 :iUN ~ 7 2008 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other OAS, Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension ~ C ,C~a~~s Change Approved Program ~ Operat. Shutdown ~ Perforate Q' Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ ~ Exploratory 2o3-os2o 3. Address: P.O. Box 196612 Stratigraphic Service '. 6. API Number: Anchorage, AK 99519-6612 50-029-23157-00-00 ~ 7. KB Elevation (ft): 9. Well Name and Number: 71.97 KB < MPS-32 ~ 8. Property Designation: 10. Field/Pool(s): , ADLO-380109 ~ MILNE POINT Field/ SCHRADER BLFF OIL Pool 11. Present Well Condition Summary: Total Depth measured 10679 ~ feet Plugs (measured) None true vertical 3876 feet Junk (measured) None Effective Depth measured 10679 ~ feet true vertical 3876 ~ feet Casing Length Size MD TVD Burst Collapse Conductor 110' 20" 92# H-40 35' - 110' 35' - 110' 1490 470 Surface 3173' 10-3/4" 45.5# I-80 34' - 3173' 34' - 3173' 5210 2480 Production 7543' 7-5/8" 29.7# I-80 33' - 7543' 33' - 3900' 6890 4790 Liner 3224' 4-1/2"12.6#x9.5# I-80 7452' - 10676' 3873' - 3876' 8430 7500 Perforation depth: Measured depth: SEE ATTACHED True Vertical depth: Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 30 - 7331 3-1 /2" 9.3# L-80 7331 - 7398 Packers and SSSV (type and measured depth) Baker S-3 Packer 7342 4-1 /2" Baker ZXP Packer 7452 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~~''~N~~ JU~ ~ ~ ~~dU U Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 278 45 0 0 147 Subsequent to operation: SI 0 0 0 0 14. Attachments: 15. Well Class after proposed work: copies of Logs and surveys Run Exploratory Development ~' Service ~ Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG ~ GINJ WINJ 3~ WDSPL ~' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 6/13/2008 ~ R ~ ~ i~S10, Form 10-404 Rev' d 04/2006 i ~ V°~3 (~` ~~ /~ ~ ~ ~ ,)l,~} ~ ~ 20~$ Submit Original Only t' ~ t '"1 ~ , F°Li~ • MPS-32 203-092 PERF ATTACHMENT Operation Date Perf O eration Code Meas De th Top Meas Depth Base Tvd Depth Top Tvd Depth Base 6/28/03 OH 10,676. 10,679. 3,876.32 3,876.01 6/28/03 SL 7,803. 7,840. 3,952.46 3,954.43 6/28/03 SL 7,883. 7,920. _ 3,955.11 3,954.26 6/28/03 SL 7,963. 8,000. 3,952.45 3,951.18 6/28/03 SL 8,043. 8,081. 3,949.72 3,947.9 6/28/03 _ SL 8,123. 8,161. _ 3,945.77 3,944.05 _ 6/28/03 SL 8,203. 8,240. 3,942.21 _3,940.43 6/28/03 SL 8,283. 8,320. 3,938.97 3,938.37 6/28/03 SL 8,363. 8,401. ( 3,937.62 3,937.54 ___ 6/28/03 SL 8,443. 8,480. 3,938.56 3,940.07 _ 6/28/03 SL 8,522. 8,560. 3,941.74 3,942.34 _ 6/28/03 SL 8,602. 8,640. 3,942.4 3,942.91 __ 6/28/03 SL 8,683. _ 8,720. 3,944.08 3,944.94 6/28/03 SL 8,763. 8,801. 3,945.69 3,946.31 6/28/03 SL 8,844. 8,881. 3,947.45 3,947.39 6/28/03 SL 8,923. 8,961. 3,946.27 3,945.31 6/28/03 SL 9,003. 9,041. 3,943.85 3,942.19____ 6/28/03 , SL 9,083. _ 9,120. __ 3,939.87 ( 3,937.31 6/28/03 i SL 9,161. 9,199. 3,934.32 3,932.14 6/28/03 ~ SL 9,240. 9,278. 3,930.47 3,928.94 _ 6/28/03 SL 9,320. 9,358. 3,927.8 3,927.32 6/28/03 SL 9,400. 9,437. 3,927. 3,926.82 6/28/03 SL 9,480. 9,517. 3,927.56 3,928.48 6/28/03 SL 9,559. 9,596. 3,928.89 3,928.57 6/28/03 SL 9,639. 9,677. 3,927.79 3,926.99 6/28/03 SL 9,719. 9,757. 3,925.87 3,925.49 _ 6/28/03 SL 9,799. 9,837. 3,925.36 3,925.14 6/28/03 SL 9,879. 9,916. 3,924.26 3,922.53 ___ _ 6/28/03 SL __ 9,959. 9,997. 3,920.33 3,918.08 6/28/03 SL 10,039. 10,077. 3,914.83 3,911.49 6/28/03 SL 10,119. 10,156. 3,908.16 3,906.12 6/28/03 SL 10,199. 10,237. _ 3,904.38 3,902.77 6/28/03 SL 10,280. 10,316. 3,901.34 3,900.42 6/28/03 SL 10,359. 10,397. 3,899.23 3,897.94 _ 6/28/03 SL 10,439. 10,476. 3,896.48 3,894.13 6/28/03 SL 10,514. 10,551. 3,891.49 3,888.75 6/28/03 SL 10,588. 10,630. 3,885.34 3,881.07 6/6/08 APF 10,200. 10,300. 3,904.33 3,900.82 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP RIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR D PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET _ FIL FILL SOF iQUEEZE FAILED MIR ANICAL ISOLATED REMOVED SOZ SQUEEZE MIS IECHANICAL ISOLATED STC ,DDLE PACK, CLOSED MLK MECHANICAL LEAK STO ADDLE PACK, OPEN OH OPEN HOLE • • MPS-32 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY -- , 6/4/2008--CTU #5. Fish Jet Pump. MIRU CTU. *"*<InterACT is Publishing>"'* Makeup ;BHA #1: Baker Fishing string with 4" G-Spear. RIH to pull Jet Pump. Latched .:into Jet Pump and PU to 21 k -9k over and pulled free, RBIH and PU again and pulled to 14k -2k over and POOH to check for Pump. Jet Pump Pulled, RIH to ', ',shift Sliding Sleeve '''.*** Job continued on WSR 6/5/08'`"`% 6/5/2008; CTU #5 Shift Sliding Sleeve / Mem Log for Depth Control /Perforate. Job :continued from WSR 6/4/08 **'`<InterACT publishing>*~* Continue RIH to close slidina sleeve. Enaaaed slidina sleeve at 7281' ctmd and shifted closed with 2k o~ verpull. POOH. Makeup BHA #3, PDS memory logging tools in carrier and `2.5" JSN. RIH to 10425' ctmd with no tag. Liner appeared to be clear. Log -:from 10425' to 9400' ctmd, flagging pipe at 10100'. Continue logging from ;'.7700' to 6600' ctmd for jewelry log. Good data recovered from logs. Tie into ;.,Sperry-Sun MWD (ROP-DGR-EWR) log, dated 18-Jun-03. Correction +13'. :,Makeup 25' PowerFlow 2.25" HSD (PF2306 HMX loading) gun #1. RIH and 'correct at flag to top shot depth. Perforate from 10275' to 10300' using 36 bbls of 1 %KCI. Make up 2nd set of guns &RIH and correct at flag to top shot depth. Perforate from 10250' to 10275' using 36 bbls of 1 %KCI. POOH /Guns ';,Fired. MU 3rd set of guns. '''***Job Continued on WSR 6/6/08 *** 6/6/2008 CTU #5 Perforate. *** Job continued from WSR 6/5/08'`** <InterACT is Publishing> Makeup 25' PowerFlow 2.25" HSD (PF2306 HMX loading) Make ', up 3rd set of guns &RIH and correct at flag to top shot depth. Perforate from ;,10225' to 10250' using 36 bbls of 1 %KCI. POOH /All Shots Fired. MU 4th set ''of guns and RIH. Correct at flag to top shot (+26'), RIH and perforate from 10200' to 10225'. POOH and freeze protect well with 40 bbls of 50/50 meth. "All shots fired. RDMO CTU. Notify DSO of wellstatus. Final WHP = 26 / 0 / 0. *'`'`Job complete**'` FLUIDS PUMPED BBLS 76 1 % KCL W/0.6% SAFELUBE 88 50/50 METH 164 TOTAL • ~~ ~~ T~i4/~f i~/CAL --;: ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 • RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 and ~~~ ~u~ ~ ~~ zoa~ Pr~aActive::[]iagnost~ Ser~rices, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C / Anchorage, AK 99518 ~~~~~o~ ! ~~1~ Fax: (907) 24S-8952 1) Jewelry Log /Coil Flag 05,1un-08 2) Signed Print Name: MP 5-32 Date : , PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 Fax: (907)245-88952 E-MAIL ""'.~~_.~~„?LU ,(a)T^~ ~_.~,; WEBSITE F,.: -9.1 , E~ 50-029-23157-00 C:\Documents and Settings\lhvnet\Desktop\Ttansmit_BP.dac • • .~.~.. _~ MICROFILMED 03/01/2008 DO NOT PLACE ... ~Y ~:~ .~. -_ ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFichelCvrPgs_InsertslMicrofilm Marker.doc e e WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 JD'j~Oq(~ Febmary 16, 2006 - f'Q~B~ RE: MWD Formation Evaluation Logs MPS-32, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 MPS-32: LAS Data & Digital Log Images: 50-029-23157-00 1 CD Rom MDJJi) 21 rF9/tXp "') q \ If\k. Â~~ ,-= r:1-- . \J \ DATA SUBMITTAL COMPLIANCE REPORT 7/6/2005 J'p4..¿ / f! J ~ ~ rrù:> API No. 50-029-23157-00-00 ./ Operator BP EXPLORATION (ALASKA) INC Permit to Drill 2030920 Well Name/No. MILNE PT UNIT SB S-32 MD 1 0679 .,.--- 3876 / Completion Date 6/29/2003 Completion Status TVD --- REQUIRED INFORMATION Mud Log No Samples No -~--_._- ------ DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, GYRO, IFR, CASANDRA, RES, ASI, PWD Well Log Information: Log/ Data Digital Type Med/Frmt ¡ RP¡---- ;~ Electr Dataset Number Name Camm3 R3Y t>fl" ~'.,J.'''~ . Directional Survey Log Log Scale Media Run No final final J J I i ),RPt tlJD D Lis .;2~--- Well Cores/Samples Information: ,~ Directional Survey final 1,2,3 1,2,3 11841 Induction/Resistivity 11841 LIS Verification Name Interval Start Stop Received Sent ADDITIONAL INFORMATION Well Cored? Y /~ Chips Received? ~ Daily History Received? Formation Tops Analysis Received? ~ --"-- Comments: Compliance Reviewed By: ~ 1-01L Current Status 1-01L UIC N Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint) Interval OH/ Start Stop CH Received Comments 0 641 Open 7/16/2003 Gyro 641 10679 Open 7/16/2003 641 10679 Open 7/16/2003 MWD 67 10679 Open 8/29/2003 MWD, GR, EWR4, ROP 67 10679 Open 8/29/2003 MWD, GR, EWR4, ROP Sample Set Number Comments .--, (VN &/N -~...."'- Date: jS- ~ÅJL~Ò ) ) :9.03 -9 ~ * I t ~J.{' WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 August 28, 2003 RE: MWD Formation Evaluation Logs l\1PS-32, AK-MW-25 00 145 1 LIS formatted Disc with verification listing. API#: 50-029-23157-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: ~ dq~F) ~ Signe~\~,~~~ - EI\/~.=r~ @: - ~. tÞ= Ü '¡, r~ !¡~-, C ' ' . 6,.,. W AU ¡..... ..... (i ." ,,,, " -; .\J ~, '1' ," -' , '-', '-. J ... 'o' 4' ". ,\\~~1\(\ð f~~~~ks C·~: ~\'. G:::,~~,: .~~~::,~,~~:.'. ~,"::(,;':;'i~':;:;Sì~~~~ )J~~~~ ;;,~' t sJf ,~I.~ ':: ) STATE OF ALASKA >- ALASKA OIL AND GAS CONSERVATION COMIVII$SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: iii Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 3259' NSL, 383' WEL, SEC. 12, T12N, R10E, UM Top of Productive Horizon: 494' NSL, 204' WEL, SEC. 02, T12N, R10E, UM Total Depth: 9. Plug Back Depth (MD+ TVD) 3533' NSL, 2137' WEL, SEC. 11, T12N, R10E, UM 10679 + 3876 4b. Location of Well (State Base Plane coorßi~~:~~' Total Depth (MD+ TVD) Surface: x- 565627 y- _ 6002~5ðZÖ,{t?"~ASP4 10679 + 3876 TPI: x- 560505 Y- 6002396 Zone- ASP4 11. Depth where SSSV set Total Depth: x- 558592 Y- 6000141 Zone- ASP4 N/A MD 19. Water depth, if offshore 18. Directional Survey iii Yes 0 No N/A MSL No. of Completions One Other 5. Date Comp., Susp., or Aband. 6/29/2003 / 6. Date Spudded / 6/18/2003 7. Date T. D. Reached 6/26/2003 ,/ 8. Elevation in feet (indicate KB, OF, etc.) KBE = 71.97' 1b. Well Class: iii Development 0 Exploratory o Stratigraphic 0 Service 12. Permit Number 203-092 13. API Number 50- 029-23157-00-00 14. Well Number M PS·32 15. Field and Pool Milne Point Unit / Schrader Bluff Ft Ft 16. Lease Designation and Serial No. ADL 380109 17. Land Use Permit: Milne Point Unit 20. Thickness of Permafrost 1800' (Approx.) 22. "CASiNG" '''·.,''"SIZEi' ' 20" 1 0-3/4" 7-5/8" 4-1/2" x 4" 21. Logs Run: MWD , GR , GYRO, IFR , CASANDRA , RES, ABI , PWD CASING, LINER AND CEMENTING RECORD ':'. !';,!,.Séj:~jNß·OER:IH,:·"I·.".."I' ,I'..'".:::IHºM¡¡~'" :;:'!: I :' "~, " 'è " ,1,', I" I" I'¡:¡'~ ,,' " I, I ,..,1.:1 '''I'I,.,,,'~'P:I'''I :I','I,!,I' ,,:,1.';., . ~~,¡"OM':' ,'''' "I","" ,\:) . :'1:, "II""",;.., " 1,,1 I \,,of, ",", '"'"",.,1.,, ,\l..fI,t':I,l ' ',.' """'i' ".,1 '",.."," .11 I I 35' 110' 42" 260 sx Arctic Set (Approx.) 35' 3173' 13-1/2" 595 sx PF 'L', 275 sx Class 'G' 33' 7543' 9-7/8" 425 sx Class 'G' 7452' 10676' 6-1/8" Sand Screens Liner I :; : I ',' : ' : .: I ,I; ",' , ~ I' , : ~ ' I : :: :: ' : ~ ; :, :1: : :' : I ;,: : I 'i :: Ii: ' i :: ; !IWrr;~;'~!'Rlt;" '; (. "I':. :. ,.',.i.".. ..',1 :;':'.'. ' ,'. 'I.~' I: ;.: I' , I ,I"I',i ~:: ': .,'.': ., ' " ..','. .,'; :' " ;: ',,; ,'" ". ,..,'1. , ;; , I, ' ;' :;: I!i, : ,;1 .u.. ;'! 1',,',,:::ii:il:'I'1 1.IÄM~l:,JNI ('P~.LI-EØ'~ ...... I' ..!."" 92# 45.5# 29.7# 12.6# x 9.5# H-40 L-80 L-80 L-80 23. Perforations oRen to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 4",9.5#, L-80 Sand Screens MD TVD MD TVD SIZE 4-1/2", 12.6#, L-80 ·.·:r~BINci!RE60RÐ'.·'·" DEPTH SET (MD) 7398' PACKER SET (MD) 7342' 7723' - 10630' 3946' - 3881' ~_." ;,:;.:);\':¡; t-c'ÍÎûÑl \ \'I'I-c ! ~ ')iI";.) C ~'I ~ _~~Z9.:<2.2 : \VT::\: 11 ::i!': L:~:,--~-=_:, 2'~:' . ',; ..' ··ÅcPIEAAç~Uk~,¢ÊMEN+$Q~ÈEZE,.....E....T......,6.. .,'.'. ' I ,I ",' : 1 ":':', I,: 'I ' 1 ,/,,' :~,; ':'" ". ','~' I..,' "', ,,',,' ,:,' ,I, ':": '" ,,',' ,:, " ,,: : I,' , ',),,', " ' " .": ,! , DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 100 Bbls of Diesel. 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): July 23, 2003 Flowing Date of Test Hours Tested PRODUCTION FOR Oll-Bsl 7/29/2003 6 TEST PERIOD + 1246 Flow Tubing Casing Pressure CALCULATED ..-aa.. Oll-Bsl Press. 24-HoUR RATE""'" GAs-McF 233 W A TER-BSl o GAs-McF W A TER-BSl CHOKE SIZE GAS-Oil RATIO 187 Oil GRAVITY-API (CORR) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil. gas or water (attach sepa~.ate,.sheetì ifnec~ssary), Submit core chips; if none, state "none". ,~- . -j None f8DMS 8Fl AUG 1 1 ¿uu, Form 10-407 Revised 2/2003 i'\,nn'i CONTINUEO ON REVERSE SIDE G\-O R \ G \ ¡ A I 28. ) GEOLOGIC MARKERS 29. JORMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None", NAME MD TVD Top Ugnu Zone C1 7012' Top of Ugnu Zone B 7046' Top of Ugnu Zone BLower 7149' SBF2-NA 7493' SBF24-MF 7606' SBF1-NB 7626' SBF1·NBR 7715' 3722' None 3732' 3766' 3886' 3918' 3924' 3945' 30. List of Attachments: Summary of Daily Drilling Reports, Surveys and a Leak-Off Test Summary. 31. I hereby certify that the f~Oing ~~orrect to the best of my knowledge. Signed sondr~wman~~4~}__ Title Technical Assistant Date 06-D1·0.3 MPS-32 203-092 Prepared By Name/Number: Sondra Stewman, 564-4750 Well Number Drilling Engineer: Matt Green, 564-5581 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken. indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 ) ') BPEXPLORATION .. Ç)peratiór1s Suq,h1ary RePPrt Legal Well Name: MPS-32 Common Well Name: MPS-32 Spud Date: 6/17/2003 Event Name: DRILL +COMPLETE Start: 6/17/2003 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/29/2003 Rig Name: DOYON 14 Rig Number: Date From 7" To Hours Task Code NPT Phase· 6/17/2003 10:00 - 10:30 0.50 MOB P PRE Skid rig floor to move position 10:30 - 12:00 1.50 MOB P PRE Move rig off well MPS-09i to Well MPS-32 12:00 - 12:30 0.50 MOB P PRE Move over well MPS32 - Skid rig floor to drlg position 12:30 - 13:00 0.50 RIGU P PRE Rig up rig floor and take water into pits - (ACCEPT rig at 13:00 hrs 6/17/2003) 13:00 - 15:30 2.50 RIGU P PRE Nipple up Divertor system - flow lines - turn buckles 15:30 - 17:00 1.50 RIGU P PRE Load 4" drill pipe into pipe shed - mix spud mud 17:00 - 00:00 7.00 DRILL P SURF Pick up / Make up 4" drill pipe and stand back in derrick 6/18/2003 00:00 - 03:30 3.50 DRILL P SURF Pick up / Make up 4" drill pipe - Rack in derrick 03:30 - 04:30 1.00 DRILL P SURF Pick up 5" hwdp - Jars 04:30 - 06:00 1.50 DRILL P SURF PJSM - Cut drilling line - Top drive service - Drawworks service 06:00 - 07:00 1.00 DRILL P SURF Make up 6 1/4" Flex dc's - stand in derrick - Make up 8" flex dc's - stand in derrick - 07:00 - 09:00 2.00 DRILL P SURF Pick up 8" motor - make up bit - orient - Rig up Gyro tools - (Motor is medium speed vs slow speed as normal picked up) 09:00 - 09:30 0.50 DRILL P SURF Pre spud meeting with all drlg personnel 09:30 - 13:00 3.50 DRILL N RREP SURF Rig repair - Accumulator - Starter on electric motor failed - repaired with transformer off Doyon 141- 13:00 - 13:30 0.50 DRILL P SURF Function test Divertor system - Preform Accumulator test - Fill stack with mud - Circulate surface system, checking for leaks 13:30 - 00:00 10.50 DRILL P SURF Spud in well MPS-32 - Drilling from 112' to 911' - wob 1 OK to 45K - RPM 80 - TO on 5K - Off 2K - GPM 425 - PP on 1500- Off 1200 - PU 90K - SO 90K - ROT 90K - 7 Gyro surveys were taken - Rigged down after drilling to 800' 6/19/2003 00:00 - 13:30 13.50 DRILL P SURF Directional Drill from 911' to 3180' - T.D. 131/2" surface hole- WOB 35K to 40K - RPM 80 - TO on 9K - off 6K - GPM 481 - PP on 2500 - off 2140 - PU 108 - SO 75 - ROT 95 13:30 - 16:00 2.50 CASE P SURF Circulate 3 X bottoms up 15,000 strokes - GPM 481 - PP 2250 - RPM 100 - TO 6K 16:00 - 18:00 2.00 CASE P SURF Pump out to HWDP - GPM 481 - Full drilling rate - Hole in good condition 18:00 - 19:00 1.00 CASE P SURF RIH from 825' to 3180 - No problems - Hole in good shape 19:00 - 21 :00 2.00 CASE P SURF Circulate 3 X bottoms up 15,000 strokes - GPM 481 - PP 2250 - RPM 100 - TO 6K 21 :00 - 23:00 2.00 CASE P SURF Pump out to HWDP - GPM 481 - Full drilling rate - Hole in good shape 23:00 - 23:30 0.50 CASE P SURF Change elevators from 4" to 5" - Stand back 5" HWDP - 61/4" Flex DC's 23:30 - 00:00 0.50 CASE P SURF Lay down 8" BHA 6/20/2003 00:00 - 01 :00 1.00 CASE P SURF Con't Lay down 8" BHA 01 :00 - 02:00 1.00 CASE P SURF PJSM - Rig up 103/4" casing tools - Change bails - pick up elevators - Make up Franks fill up tool - Set casing slips - Tongs 02:00 - 05:00 3.00 CASE P SURF Pick up Float Joints - RIH - Fill - Check Floats - Run total 76 joints 10 3/4" 45.5# L-80 BTC casing - Make up landing joint - Land on hanger - Shoe depth 3173' - Float Collar 3087' - From 2400' to 3140' casing string taking weight work / push casing to bottom 05:00 - 05:30 0.50 CASE P SURF Make up landing joint - Land casing - Shoe depth 3173' - Float collar 3087' - Break out / Lay down Franks fill up tool - Rig up Howco cementing head - Rig up cementing lines - Break circulation 05:30 - 06:30 1.00 CASE P SURF Circulate - Condition mud - For cementing 10 3/4" casing Printed: 6/30/2003 1 :48:51 PM ) ) ·aPEXP40RATION Operation~ Summary ~eport . Page2of6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-32 MPS-32 DRILL +COMPLETE DOYON DRILLING INC. DOYON 14 Start: 6/17/2003 Rig Release: 6/29/2003 Rig Number: Spud Date: 6/17/2003 End: Hours Task Code NPT Phase D$scfiptiOliofOþerations 6/20/2003 06:30 - 09:00 2.50 CEMT P SURF Pump 10 bbls water - Test lines to 3500 psi - Pump 10 bbls water @ 5 bpm - 250 psi - Pump 50 bbls Alpha spacer mixed at 10.2 ppg (one gallon dye first 5 bbls of spacer slurry) @ 6.5 bpm - 275 psi - Drop bottom plug last 5 bbls of spacer - Mix and pump 595 sxs 440 bbls of 10.7 Type "L" Yield 4.15 cf/sx of lead cement - 275 sxs 56 bbls 15.8 ppg - Class 'G' yield 1.15 cf/sx @ 5 bpm 550 psi - Kick out top plug with 30 bbbls water from Howco - Displace with rig with mud 267 bbls @ 9 bpm 800 psi - bump plug with 1500 psi - blled off pressure floats held CIP 09:00 hrs - Total of 129 bbls good cement back to surface - Wash out 57.5% over gauge hole 09:00 - 10:00 1.00 CASE P SURF Rig down Howco cementing head - lines - Back out 1 lay down landing joint - Rinse divertor - Lay down casing tools 10:00 - 10:30 0.50 CASE P SURF Nipple down Divertor system 10:30 - 11 :00 0.50 CASE P SURF Nipple up casing head - Tubing spool - Test casing head to 1000 psi - 10 mins 11 :00 - 13:30 2.50 CASE P SURF Nipple up Bop's 13:30 - 14:00 0.50 CASE P SURF Rig up to test - Install test plug 14:00 -17:30 3.50 CASE P SURF Test BOP's - Annular 250 low 3500 high - 5 mins each test - Top rams - Bottom rams - Blind rams - Choke manifold - Hyd Choke 1 Kill - Manual Choke 1 Kill - Floor TIW - Floor dart valve - Upper 1 Lower IBOP - 250 low 3500 high - 5 mins each test- Accumulator test - all test good - John Spaulding with AOGCC wavied witness of the test 17:30 - 18:00 0.50 CASE P SURF Rig down testing equipment - Pull test plug - Install wear ring - Close annulus valve 18:00 - 20:00 2.00 CASE P SURF Make up 9 7/8" BHA - surface test MWD @ 104 stks @ 940 psi 20:00 - 20:30 0.50 CASE P SURF Rig Service - Top Drive - Drawworks 20:30 - 21 :30 1.00 CASE P SURF RIH to 3024' 21 :30 - 22:30 1.00 CASE P SURF Break circulation - Test 10 3/4" casing to 2500 psi for 30 minutes 22:30 - 23:30 1,00 DRILL P SURF Drill float equipment - clean out to 3180' - Drill 20' new hole to 3200' 23:30 - 00:00 0,50 CASE P SURF Circulate condition mud to run FIT 6/21/2003 00:00 - 00:30 0,50 EVAL P SURF Run FIT - TVD 2400 - Mud weight 9.1 = 11.5 EMW 00:30 - 04:30 4.00 DRILL P INT1 Directional Drill from 3200' to 3908' - WOB 35K to 40K - GPM 450 - PP 2500 on 2300 off - RPM 120 - TO on 9K - off 5K - PU 125K SO 85K - ROT 90K 04:30 - 05:00 0.50 DRILL N HMAN INT1 Flowline 1 shaker box plugged up with clay balls - Clean out flowline and shaker box 05:00 - 05:30 0.50 DRILL P INT1 Directional drill from 3908' to 3982' - WOB 35K to 40 K - RPM 120 - TO on 9K - off 5K - GPM 450 - PP on 2550 - off 2400 - PU 125K - SO 85K - ROT 90K 05:30 - 06:00 0.50 DRILL N SFAL INT1 Conveyor # 2 plugged off at rock washer dump - unplug 06:00 - 11 :30 5.50 DRILL P INT1 Directional drill from 3982' to 5009' - WOB 35K to 40K - RPM 120 - TO on 8K - off 6K - GPM 450 - PP on 2700 - off 2600 - PU 132K - SO 80K - ROT 100K 11 :30 - 13:00 1.50 DRILL P INT1 Circulate 3 X - GPM 450 - PP 2240 - RPM 120 - TO 7K 13:00 - 15:00 2.00 DRILL P INT1 Pump out from 5009' to 3171' - Pump out at drilling rate - GPM 450 - PP 2200 - Hole in good shape 15:00 - 15:30 0.50 DRILL P INT1 Rig Service Printed: 6/30/2003 1 :48:51 PM ) ) . BPEXPLORATION Operations SummélryReport Page 3 Of6 Legal Well Name: M PS-32 Common Well Name: MPS-32 Spud Date: 6/17/2003 Event Name: DRILL +COMPLETE Start: 6/17/2003 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/29/2003 Rig Name: DOYON 14 Rig Number: Bate From "'To Hours Task Code NPT 6/21/2003 15:30 - 16:00 0.50 DRILL P INT1 RIH from 3171' to 5009' - No problem 16:00 - 00:00 8.00 DRILL P INT1 Directional drill from 5009' to 6290' - WOB 35K to 45K - RPM 120 - TO on 10K - off 8K - GPM 450 - PP on 3200 - off 2850- PU 150K - SO 70K - Rot 105K 6/22/2003 00:00 - 14:30 14.50 DRILL P INT1 Directional Drill from 6290' to 7555 -T.D. 97/8" Hole - WOB 35K - RPM 120 - TO on 12K - off 10K - GPM 481 - PP on 3100 - off 3000 - PU 155K - SO 80K - ROT 11 OK - (Top Ugnu 6240 MD 3470 TVD) 14:30 - 17:30 3.00 CASE P INT1 CBU 3 X - 20,000 stks - GPM 500 - PP 3150 - RPM 120 - TO 9K 17:30 - 20:30 3.00 CASE P INT1 Pump Slug - POH from 7555' to 5900' - Hole swabbing - Pump out at drilling rate 500 gpm - from 5900' to 4650' - POH wlout pump to shoe to 3171' 20:30 - 21 :00 0.50 CASE P INT1 Rig service 21 :00 - 22:30 1.50 CASE P INT1 RIH from 3171' to 7555' 22:30 - 00:00 1.50 CASE P INT1 CBU 3 X - 11000 stks - GPM 500 - PP 3150 - RPM 120 - TO 9K 6/23/2003 00:00 - 01 :30 1.50 CASE P INT1 Con't CBU 3 X - 9000 stks - GPM 500 - PP 3150 - RPM 120 - T09K 01 :30 - 02:00 0.50 CASE P INT1 Monitor well - well static - Pump slug 02:00 - 03:30 1.50 CASE P INT1 POH from 7525' to Shoe 3171'- 03:30 - 04:30 1.00 CASE P INT1 POH from 3171' to BHA 825' 04:30 - 06:30 2.00 CASE P INT1 Change out 4" to 5" elevators - Stand back 1 stand 5" hwdp - Lay down BHA - Flush MWD - Motor with water 06:30 - 07:00 0.50 CASE P INT1 Clear rig floor 07:00 - 07:30 0.50 CASE P INT1 Pull wear ring - Install test plug 07:30 - 09:00 1.50 CASE P INT1 Change top rams to 7 5/8" rams - test door seals to 1500 psi for 10 mins 09:00 - 09:30 0.50 CASE P INT1 Rig up to run 7 5/8" casing - Make up Franks fill up tool - Casing tongs - Bails - Elevators 09:30 - 10:30 1.00 CASE P INT1 Pick up float joints - Baker lok 1 st three joints - check floats 10:30 - 13:00 2.50 CASE P INT1 Con't running 7 5/8" - L-80 - 29.7# - BTC casing to 3140' 13:00 - 14:00 1.00 CASE P INT1 Circulate Casing volume 265 bbls @ 6 bpm - Psi 400 14:00 - 17:00 3.00 CASE P INT1 Con't run 75/8" casing from 3140' to 7387' 17:00 - 17:30 0.50 CASE P INT1 Pick up Landing joint - Land casing @ 7543' - Break out Franks fill up tool - Make up Howco Cementing head - Make up circulating lines - Break Circulation 17:30 - 19:30 2.00 CASE P INT1 Circulate I Condition mud for cement job - 6 bpm - PP 380 psi - Reciprocate pipe 20' strokes - 1 spm - while circulating - PU 220K - SO 90K 19:30 - 20:30 1.00 CEMT P INT1 Pump 5 bbls water - Test lines to 3500 psi - Pump 15 bbls water - Pump 30 bbls Alpha spacer mixed at 10.2 - (Drop bottom plug last 5 bbls Alpha spacer pumped) - Pump 425 sxs Class "G" with 3% KCL - 1 % Cal Seal - .6% Lap - Yeild 1.21 cu/ft sx - mixed at 15.6 ppg - 91 bbls pumped 20:30 - 21 :30 1.00 CEMT P INT1 Drop bottom plug - Howco kicked out plug with 20 bbls water - Rig displaced with 313 bbls mud 9.2 ppg - Displacement rate 6 bpm - 100 psi to 480 psi - Bumped plug with 1000 psi over - 1500 psi - Held pressure 3 mins - bleed off - Floats held - (pump efficient rate 97%) 21 :30 - 22:00 0.50 CEMT P INT1 Lay down Landing Joint - Clear rig floor 22:00 - 23:00 1.00 CASE P INT1 Install 7 5/8" X 10 3/4" pack-off - test to 5K for 10 mins 23:00 - 00:00 1.00 CASE P INT1 Change top rams from 75/8" to 2 7/8" X 5" - Install test plug - Printed: 6/30/2003 1 :48:51 PM '.) ) Bp· E:XPLORAn-ION Operafiòns·.·SumrnCl ry.. ·RepQr1: Legal Well Name: MPS-32 Common Well Name: M PS-32 Spud Date: 6/17/2003 Event Name: DRILL +COMPLETE Start: 6/17/2003 End: Contractor Name: DOYON DRILLING INC. Rig Release: 6/29/2003 Rig Name: DOYON 14 Rig Number: Hours Täsk Code NPT 6/23/2003 23:00 - 00:00 1.00 CASE P INT1 Rig up to test rams - Test rams 6/24/2003 00:00 - 00:30 0.50 CASE P INn Con't Testing 2 7/8" X 5" rams to 250 low - 3500 high - 5 mins each test - Rig down testing equipment - Pull test plug - Install wear ring - close annulus valves 00:30 - 01 :00 0.50 CASE P INT1 Inspect saver sub - Pick up MWD tools from beaver slide - 01 :00 - 02:30 1.50 CASE P INT1 Make up BHA # 3 02:30 - 03:00 0.50 CASE P INT1 Change out to 4" handling equipment - Shallow test MWD - test good 03:00 - 06:00 3.00 CASE P INT1 RIH with BHA # 3, to 7,418 06:00 - 07:00 1.00 CASE P INT1 Test 7 5/8 csg to 3,500 psi for 30 min. 07:00 - 08:30 1.50 DRILL P INT1 Drill float and shoe and 20 ft of new hole to 7,575' 08:30 - 09:30 1.00 DRILL P INT1 Circ and condition mud for FIT 246 gals per min. 40 rpms, 1600 psi 09:30 - 10:00 0.50 CASE P INT1 FIT test 490 psi 8.6 mud wt., TVD 3900 = EMW 11.0 10:00 - 11 :00 1.00 CASE P INT1 Pump Flo-PRO spacer, displace hole with 9.5 # FLO-PRO 11 :00 - 11 :30 0.50 CASE P INT1 Obtain PWD baseline 11 :30 - 00:00 12.50 DRILL P PROD1 Directional drill 7,575 to 8279' with 245 gals per min. 2240 psi, 80 rpms, AST 5, ART 5.25, ECD 11.3 6/25/2003 00:00 - 00:00 24.00 DRILL P PROD1 Directional drill 8279' to 10,057' with 245 gals per min. 2750 psi, 80 rpms, ECD 12.35, AST 5.83, ART 11.83 6/26/2003 00:00 - 00:30 0.50 DRILL P PROD1 Directional drill 10,057' to 10101' with 245 gals per min. 2750 psi, 80 rpms, ECD 12.58 00:30 - 02:30 2.00 DRILL P PROD1 Circ, two bottoms up with 80 rpms 245 gals, 2600 psi, trying to clean up hole ECD dropped from 12.58 to 12.2 02:30 - 11 :00 8.50 DRILL P PROD1 Directional drill 1 0, 101' to 10,679 TO with 245 gals per min. 2750 psi, 80 rpms, ECD 12.25 11 :00 - 13:30 2.50 CLEAN P COMP Circ. Three bottoms up with 280 gals min. 100 rpms 2580 psi Starting ECD 12.42 Final ECD 12.29 13:30 - 16:30 3.00 CLEAN P COMP Pumping out to 7542, 7 5/8 csg shoe with full drilling rate. record torque and drag every 5 stands 16:30 - 17:00 0.50 CLEAN P COMP Service rig 17:00 - 19:30 2.50 CLEAN P COMP Slug pipe, Trip out to BHA, record torque and drag every 5 stands 19:30 - 20:30 1.00 CLEAN P COMP Laying down BHA 20:30 - 21 :00 0.50 CLEAN P COMP Pull wear ring 21 :00 - 00:00 3.00 CLEAN P COMP Testing BOPS and Manifold 250-3,500 psi for 5 min. per test. Hydrill 250- 2500 psi for 5 min per test,The right to witness test was wavier by Chuck Scheeve AOGCC. 6/27/2003 00:00 - 01 :00 1.00 CLEAN P COMP Pickup BHA, surface test PWD tool 01 :00 - 03:30 2.50 CLEAN P COMP Tripping in to 7468, fill DP ever 25 stands 03:30 - 04:30 1.00 CLEAN P COMP Cut Drilling line and service top drive 04:30 - 05:30 1.00 CLEAN P COMP Wash and ream from 7,542 to 8,040' with hole opener 120 rpms 245 gals per min.1850 psi ECD 11.0 05:30 - 06:00 0.50 CLEAN P COMP Pull back into 7 5/8 csg shoe @ 7,542' 06:00 - 07:00 1.00 CLEAN P COMP Tripping in hole to 10,679, no problems 07:00 - 10:00 3.00 CLEAN P COMP Circ three bottoms up with 250 gals per min. starting pressure 2540 final 2460 psi, starting ECD 12.41 final 12.03, rotate 120 rpms 10:00 - 12:00 2.00 CLEAN P COMP Displace hole with solid free 9.5 Flo-Pro, pump 20 bbls viscosified spacer, 130 bbls 9.5 brine, chase with 9.5 Fro-Pro, rotate and recipate 127 Gpm 25 rpms, stage pump rate to 300 glm once spacer was in casing final ECD 11.3 with 300 gals min. 2500 psi TQ 6,000 with 25 rpms Printed: 6/30/2003 1 :48:51 PM ) ) BPEXPLORATION OperatiQnsSummaryR~p;ort . Page Sof6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-32 MPS-32 DRILL +COMPLETE DOYON DRILLING INC. DOYON 14 . Date Frorn·~ To· · Hours Task Code NPT Phase 6/27/2003 12:00 - 15:30 3.50 CLEAN P COMP 15:30 - 16:00 0.50 CLEAN P COMP 16:00 - 19:00 3.00 CLEAN P COMP 19:00 - 20:00 1.00 CLEAN P COMP 20:00 - 21 :00 1.00 CASE P COMP 21 :00 - 00:00 3.00 CASE P COMP 6/28/2003 00:00 - 00:30 0.50 CASE P COMP 00:30 - 04:00 3.50 CASE P COMP 04:00 - 05:00 1.00 CASE P COMP 05:00 - 05:30 0.50 CASE P COMP 05:30 - 07:00 1.50 CASE P COMP 07:00 - 09:30 2.50 CASE P COMP 09:30 - 10:30 1.00 CASE P COMP 10:30 - 13:30 3.00 CASE P COMP 13:30 - 15:30 2.00 CASE P COMP 15:30 - 19:00 3.50 CASE P COMP 19:00 - 19:30 0.50 CASE P COMP 19:30 - 20:30 1.00 RUNCOIVP COMP 20:30 - 21 :00 0.50 RUNCOIVP COMP 21 :00 - 22:30 1.50 RUNCOIVP COMP 22:30 - 00:00 1.50 RUNCOIVP COMP 6/29/2003 00:00 - 06:00 6.00 RUNCOIVP COMP 06:00 - 07:00 1.00 RUNCOIVP COMP 07:00 - 07:30 0.50 RIGD P COMP 07:30 - 09:00 1.50 RIGD P COMP 09:00 - 11 :00 2.00 RIGD P COMP 11 :00 - 12:00 1.00 RIGD P COMP 12:00 - 13:30 1.50 RIGD P COMP 13:30 - 14:00 0.50 RIGD P COMP Start: 6/17/2003 Rig Release: 6/29/2003 Rig Number: Spud Date: 6/17/2003 End: Description of Operations Pumping out Csg shoe with full drilling rate, tight spot at 8,500 backed ream and worked till clear up. Circ bottoms up at 7 5/8 Csg shoe @ 7542' Tripping out to BHA Lay down BHA Rig up, to pick up 4" liner, PJSM Picking up 4.5 12.6# 1-80 shoe jt, 4" screen liner C27 baker med. Excluder, IBT with 4" blank 9.5 L-80 IBT ever other jt. for a total 37 4" screen jts and 36 4" blank jts, 6 jts of 4.5 12.6 L-80 IBT on top, Baker HMC liner hanger, Baker ZXP liner top packer, Tie back sleeve Picking up 4.5 12.6# L-80 shoe jt, 4" screen liner C27 Baker med. Excluder, IBT with 4" blank 9.5 L-80 IBT ever other jt. for a total 374" screen jts and 364 blank jts, 6 jts of 4.5 12.6 L-80 IBT on top, Baker HMC liner hanger, Baker ZXP liner top packer, Tie back sleeve Tripping in hole with liner, to 10,676, no problems, liner @ shoe with 120,000 pickup, 85,000 slackoff liner on bottom with 140,000 pick up and 75,000 slack off Drop 29/32 ball and pump down 1.5 bbls min. set Hanger with 2100 psi, set packer with 3100 psi, shear ball with 4,200 Test liner top packer with 1500 psi Release from liner, Tripping out Laying down excess drill pipe Service break and lay down running tools Pickup Johnny Whacker and tripping in to 7,430 Circ and displace well with, 8.8 Nacl420 gals min, 120 rpms, followed with 9.2 Nacl treated with corrosion inhibitor. Tripping out, lay down 33 stands of pipe and stand back 45 stands in derrick Lay down Johnny Whacker, pull wear ring Rig up to run tubing and PJSM Pick up 3.5 tail pipe assembly, with Baker Premier packer, Phoenix pump and gauge Make up I-wire connections for pump and gauge Picking up 4.5 12.6# L-80 Tubing to 1780' Picking up 4.512.6# L-80 Tubing to 7398', total jts run 177 jts Hook up I-wire to penetrator, Land tUbing,with 107,000 string wt., 82000 slack offwt., 94 clamps (Wire line guide 7398, XN nipple 7392', Baker Premier 7518 x 41/27342', X nipple 7331', phonix gauge sensor 7315', sliding sleeve 7292', phoenix pressure gauge 7281', GLM 2391') Test TWC from below with 200 psi Nipple down BOPS Nipple up fmc 11 x 4 1/165000# tubing head adapter, run i-wire tru adapter, test packoff T/5K, test tree cavity T/5K, I-wire continuity test Drop ball, set packer with 4,000 psi, observer shear of packer pins @ 2300 and 3500 psi, Test Tubing to 4,000 for 30 min., Test annulus to 4500 psi for 30 min., shear RP valve Freeze protect 4 1/2 x 7 5/8 with 21 bbls of diesel and let u-tube Printed: 6/30/2003 1 :48:51 PM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ') BPEX.PLORATIQN Operätions··Surt1.mary.¡Report MPS-32 MPS-32 DRILL +COMPLETE DOYON DRILLING INC. DOYON 14 Page 6 ot6 Start: 6/17/2003 Rig Release: 6/29/2003 Rig Number: Spud Date: 6/17/2003 End: 6/29/2003 Datß From~To Hours Task Code NPT 14:00 -15:30 15:30 - 16:00 16:00 - 17:00 1.50 RIGD P 0.50 RIGD P 1.00 RIGD P caMP caMP caMP Freeze protect 10 3/4 x 7 5/8 with 79 bbls diesel Rig down circ. lines, test Equipment Rig up lubricator and install SPV, secure well Rig Release for rig move @ 1700 hrs 6/29/2003 Printed: 6/30/2003 1 :48:51 PM Legal Name: Common Name: Test Date 6/21/2003 6/24/2003 FIT FIT MPS-32 MPS-32 Test Type Test Depth (TMD) 3,200.0 (ft) 7,542.0 (ft) TestDØpth(TV[» 2,400.0 (ft) 3,900.0 (ft) SÙrtêlcePtêssorë 300 (psi) 490 (psi) AMW 9.10 (ppg) 8.60 (ppg) ····I..;~äKØffPr~sutø{@He) 1,435 (psi) 2,232 (psi) EMW 11.51 (ppg) 11.02 (ppg) -- -" Printed: 6/30/2003 1 :48:43 PM ) ) 15-Jul-03 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPS-32 GYRO Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00 I MD 0.00' MD (if applicable) 0.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager :J-O 3 -- Oc¡~ RECE\VED JUt1\.- 1 6 2.003 A1aaka œ & Gas Cons. eommiseK>n ~~ Attachment(s) Sperry..Sun Drilling Services ',.. Milne Point Unit BPXA Milne Point MPS MPS-32 GYRO Job No. AKFOOOO2500145, Surveyed: 26 June, 2003 S urv-ey Report 2 July, 2003 - Your Ref: 500292315700 Surface Coordinates: 5999924.63 N, 565627.44 E (70024' 36.8661- N, 149027' 56.2179- W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 999924.63 N, 65627.44 E (Grid) Surface Coordinates relative to Structure: 44.06 S, 717.97 W (True) Kelly Bushing: 71.97ft above Mean Sea Level Elevation relative to Project V Reference: 71.97ft Elevation relative to Structure: 71.97ft 5pa............y-su., DRILL'NG SlæFtVICeS A Halliburton Company DEF\NITIVE _7 -' Survey Ref: svy1221 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-32 GYRO Your Ref: 500292315700 Job No. AKFOOOO2500145, Surveyed: 26 June, 2003 BP EXPLORA TION (ALASKA) INC. Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 0.00 0.000 0.000 -71.97 0.00 O.OON O.OOE 5999924.63 N 565627.44 E 0.00 Tolerable Gyro 188.00 0.850 334.000 116.02 187.99 1.25 N 0.61 W 5999925.88 N 565626.82 E 0.452 0.67 279.00 1.350 335.000 207.01 278.98 2.83 N 1.36W 5999927.45 N 565626.05 E 0.550 1.48 369.00 1.800 350.000 296.97 368.94 5.18 N 2.05W 5999929.80 N 565625.34 E 0.674 2.28 459.00 2.900 340.000 386.90 458.87 8.72N 3.08W 5999933.32 N 565624.29 E 1.300 3.46 -. 549.00 4.450 322.000 476.71 548.68 13.61 N 6.01 W 5999938.18 N 565621.31 E 2.127 6.60 641.00 7.700 326.000 568.18 640.15 21.53 N 11.65 W 5999946.06 N 565615.60 E 3.560 12..59 All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 272.530° (True). Magnetic Declination at Surface is 25.468°(17-Jun-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 641.00ft., The Bottom Hole Displacement is 24.48ft.. in the Direction of 331.580° (True). Survey tool program for MPS-32 GYRO From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 641.00 640.15 Tolerable Gyro 0.00 2 July, 2003 - 9:04 Page 20f2 DrillQuest 3.03.02.005 BPXA -, ~. ) AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPS-32 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 10,679.00' MD ) 15-Jul-03 (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) :J 0 Ó ,..-0 q ")-, RECEIVED JUfJ.. 1 6 2003 Alaska lHI ... ..:JdS ~ons. CommiIeim ~~ Sperry-Sun Drilling Services Milne Point Unit BPXA Milne Point MPS MPS-32 Job No. AKZZ0002500145, Surveyed: 26 June, 2003 Survey Report 8 July, 2003 Your Ref: API 500292315700 Surface Coordinates: 5999924.63 N, 565627.44 E (70024' 36.8661" N, 149027' 56.2179" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 999924.63 N, 65627.44 E (Grid) Surface Coordinates relative to Structure: 44.06 S, 717.97 W (True) Kelly Bushing: 71.97ft above Mean Sea Level Elevation relative to Project V Reference: 71.97ft Elevation relative to Structure: 71.97ft spe..........y-5ul'1 DRILLING SEAVICeS A Halliburton Company JEF N\T\VE ~. Survey Ref: svy1223 Sperry-Sun Drilling Services Survey Report for Milne Point MPS . MPS·32 Your Ref: AP/500292315700 Job No. AKZZ0002500145, Surveyed: 26 June, 2003 BP EXPLORA TION (ALASKA) INC. BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 64 1 .00 7.700 326.000 568.18 640.15 21.53 N 11.65 W 5999946.06 N 565615.60 E 12.59 AK-6 BP _IFR-AK 759.99 10.260 330.010 685.70 757.67 37.32 N 21.41 W 5999961.76 N 565605.70 E 2.214 23.03 853.71 14.250 319.970 777.28 849.25 53.39 N 33.01 W 5999977.73 N 565593.97 E 4.811 35.33 951.01 18.960 314.650 870.50 942.4 7 73.68 N 51.96 W 5999997.85 N 565574.83 E 5.082 55.17 1046.71 24.530 309.350 959.37 1031.34 97.22 N 78.41 W 6000021.16 N 565548.18 E 6.166 82.63 1141.76 26.610 309.880 1045.10 1117.07 123.39 N 110.01 W 6000047.05 N 565516.35 E 2.201 115.35 _/ 1237.69 27.590 311.920 1130.50 1202.47 152.00 N 143.02 W 6000075.37 N 565483.09 E 1.408 149.59 1333.80 29.020 312.410 1215.12 1287.09 182.60 N 176.80 W 6000105.67 N 565449.04 E 1.507 184.69 1429.23 31.450 308.960 1297.57 1369.54 213.87 N 213.26 W 6000136.62 N 565412.31 E 3.129 222.49 1525.23 35.580 306.640 1377.59 1449.56 246.30 N 255.16 W 6000168.68 N 565370.13 E 4.504 265.78 1621.48 36.300 307.740 1455.52 1527.49 280.45 N 300.16 W 6000202.43 N 565324.83 E 1.005 312.25 1718.37 37.580 307.390 1532.96 1604.93 315.95 N 346.32 W 6000237.52 N 565278.36 E 1.339 359.92 1814.98 38.830 311.190 1608.88 1680.85 353.79 N 392.52 W 6000274.96 N 565231.82 E 2.755 407.76 1911.25 42.430 310.390 1681.93 1753.90 394.72 N 439.99 W 6000315.47 N 565184.00 E 3.778 456.98 2006.90 42.790 311.840 1752.33 1824.30 437.30 N 488.77W 6000357.62 N 565134.85 E 1.093 507.59 2101.17 43.420 310.920 1821.16 1893.13 479.88 N 537.10W 6000399.78 N 565086.14 E 0.944 557.76 2197.60 46.060 309.750 1889.65 1961.62 523.80 N 588.85 W 6000443.24 N 565034.01 E 2.868 611.40 2292.55 49.930 308.670 1953.18 2025.15 568.38 N 643.52 W ·6000487.33 N 564978.95 E 4.162 667.98 2389.07 54.4 30 306.190 2012.35 2084.32 614.66 N 704.07 W 6000533.08 N 564918.00 E 5.084 730.52 2484.33 58.840 301.900 2064.75 2136.72 659.11 N 770.00 W 6000576.95 N 564851.68 E 5.963 798.34 2580.41 63.840 300.880 2110.82 2182.79 702.99 N 841.95 W 6000620.20 N 564779.35 E 5.287 872.16 2676.50 65.140 302.150 2152.20 2224.17 748.33 N 915.87 W 6000664.88 N 564705.03 E 1.804 948.01 2772.94 67.570 301.900 2190.88 2262.85 795.17 N 990.77 W 6000711.06 N 564629.72 E 2.531 1024.90 2867.26 69.080 302.630 2225.71 2297.68 841.96 N 1064.88 W 6000757.20 N 564555.20 E 1.755 1101.01 -- 2963.91 70.940 302.390 2258.75 2330.72 890.77 N 1141.47 W 6000805.34 N 564478.18 E 1.939 1179.68 3059.41 72.570 302.030 2288.65 2360.62 939.12 N 1218.21 W 6000853.00 N 564401.02 E 1.744 1258.48 3120.14 70.620 301.920 2307.82 2379.79 969.63 N 1267.09 W 6000883.09 N 564351.88 E 3.216 1308.66 3246.28 69.390 300.550 2350.95 2422.92 1031.10 N 1368.44 W 6000943.66 N 564250.00 E 1.412 1412.62 3343.21 69.300 300.350 2385.15 2457.12 1077.06 N 1446.63 W 6000988.94 N 564171.41 E 0.214 1492.76 3438.54 70.040 300.610 2418.27 2490.24 1122.41 N 1523.66 W 6001033.60 N 564093.97 E 0.817 1571.72 3533.71 69.750 300.710 2450.98 2522.95 1167.98 N 1600.54 W 6001078.50 N 564016.70 E 0.320 1650.54 3629.90 69.300 300.760 2484.63 2556.60 1214.03 N 1678.00 W 6001123.87 N 563938.84 E 0.470 1729.95 3725.85 69.170 301.040 2518.64 2590.61 1260.11 N 1754.98 W 6001169.27 N 563861.46 E 0.305 1808.89 3822.03 68.660 301.370 2553.25 2625.22 1306.60 N 1831.74 W 6001215.09 N 563784.29 E 0.619 1887.63 3919.17 69.120 301.790 2588.23 2660.20 1354.06 N 1908.94 W 6001261.86 N 563706.68 E 0.622 1966.85 8 July, 2003 - 15:31 Page 2 0'6 DrillQlIest 3.03.02.005 Sperry-Sun Drilling··Services Survey Report for Milne Point MPS - MPS·32 Your Ref: API 500292315700 Job No. AKZZ0002500145, Surveyed: 26 June, 2003 BP EXPLORA TlON (ALASKA) INC. BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 4016.48 68.440 302.010 2623.45 2695.42 1401.99 N 1985.95 W 6001309.12 N 563629.25 E 0.730 2045.90 4112.41 68.000 302.680 2659.05 2731.02 1449.65 N 2061.21 W 6001356.12 N 563553.57 E 0.794 2123.19 4208.73 68.580 302.880 2694.68 2766.65 1498.10 N 2136.44 W 6001403.90 N 563477.91 E 0.632 2200.49 4302.59 69.110 303.330 2728.55 2800.52 1545.91 N 2209.77 W 6001451.07 N 563404.17 E 0.720 2275.85 4398.62 70.170 302.960 2761.96 2833.93 1595.14 N 2285.15 W 6001499.62 N 563328.36 E 1.161 2353.34 4495.19 71.210 302.760 2793.89 2865.86 1644.58 N 2361.70 W 6001548.40 N 563251.38 E 1.095 2432.00 4591.53 69.710 302.600 2826.11 2898.08 1693.61 N 2438.12 W 6001596.75 N 563174.53 E 1.565 2510.50 - 4687.35 69.380 301.690 2859.60 2931.57 1741.37 N 2514.13 W 6001643.85 N 563098.10 E 0.954 2588.55 4782.71 69.390 301.640 2893.18 2965.15 1788.23 N 2590.10 W 6001690.03 N 563021.73 E 0.050 2666.51 4878.80 69.570 300.940 2926.86 2998.83 1834.97 N 2667.00 W 6001736.09 N 562944.41 E 0.708 2745.40 4975.64 69.240 301.240 2960.92 3032.89 1881.78 N 2744.63 W 6001782.22 N 562866.38 E 0.447 2825.03 5070.77 69.910 300.750 2994.12 3066.09 1927.68 N 2821.05 W 6001827.45 N 562789.56 E 0.854 2903.40 5167.27 70.110 300.400 3027.11 3099.08 1973.81 N 2899.13 W 6001872.89 N 562711.08 E 0.399 2983.43 5263.84 69.310 299.560 3060.60 3132.57 2019.08 N 2977.59 W 6001917.46 N 562632.23 E 1.163 3063.81 5360.17 69.700 299.890 3094.33 3166.30 2063.82 N 3055.95 W 6001961.51 N 562553.48 E 0.517 3144.07 5456.21 69.570 299.540 3127.75 3199.72 2108.45 N 3134.14W 6002005.46 N 562474.89 E 0.367 3224.16 5552.88 69.970 299.700 3161.18 3233.15 2153.28 N 3213.00 W 6002049.59 N 562395.65 E 0.442 3304.92 5649.03 71.020 299.900 3193.28 3265.25 2198.32 N 3291.64 W 6002093.94 N 562316.61 E 1.110 3385.47 5745.35 69.250 300.570 3226.01 3297.98 2243.93 N 3369.91 W 6002138.86 N 562237.95 E 1.951 3465.67 5841 .18 69.450 300.430 3259.80 3331.77 2289.44 N 3447.17 W 6002183.69 N 562160.29 E 0.249 3544.87 5937.36 69.830 300.320 3293.27 3365.24 2335.04 N 3524.96 W 6002228.60 N 562082.09 E 0.409 3624.60 6033.78 68.960 298.990 3327.20 3399.17 2379.69 N 3603.39 W 6002272.57 N 562003.28 E 1.575 3704.92 6130.02 69.840 296.930 3361.06 3433.03 2421.92 N 3682.96 W 6002314.10 N 561923.34 E 2.202 3786.28 6225.73 70.360 294.620 3393.65 3465.62 2461.05 N 3763.99 W 6002352.51 N 561841.97 E 2.334 3868.96 -- 6321.69 71.460 293.780 3425.03 3497.00 2498.22 N 3846.71 W 6002388.95 N 561758.93 E 1.414 3953.23 6418.64 72.510 293.380 3455.01 3526.98 2535.10 N 3931.20 W 6002425.09 N 561674.11 E 1.152 4039.28 6512.96 72.190 291.310 3483.61 3555.58 2569.27 N 4014.33 W 6002458.53 N 561590.69 E 2.119 4123.83 6608.13 69.970 289.290 3514.47 3586.44 2600.51 N 4098.75 W 6002489.03 N 561506.00 E 3.078 4209.55 6703.80 69.700 286.820 3547.46 3619.43 2628.34 N 4184.13 W 6002516.11 N 561420.38 E 2.440 4296.07 6799.88 69.310 282.880 3581.11 3653.08 2651.41 N 4271.10 W 6002538.40 N 561333.21 E 3.862 4383.97 6895.73 71.140 277.160 3613.56 3685.53 2667.07 N 4359.87 W 6002553.28 N 561244.30 E 5.931 4473.35 6991.17 72.310 270.760 3643.52 3715.49 2673.30 N 4450.23 W 6002558.73 N 561153.90 E 6.484 4563.89 7086.76 71.140 267.780 3673.50 3745.47 2672.16 N 4540.97 W 6002556.78 N 561063.16 E 3.203 4654.50 7183.26 70.160 266.150 3705.47 3777.44 2667.34 N 4631.89 W 6002551.17 N 560972.29 E 1.890 4745.12 7280.38 67.700 261.560 3740.40 3812.37 2657.67 N 4721.96 W 6002540.71 N 560882.31 E 5.085 4834.68 8 July, 2003 - 15:31 Page 3 of6 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-32 Your Ref: AP/500292315700 Job No. AKZZ0002500145, Surveyed: 26 June, 2003 BP EXPLORA TION (ALASKA) INC. BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 7377.44 68.920 257.680 3776.28 3848.25 2641.41 N 4810.65 W 6002523.67 N 560793.77 E 3.921 4922.56 7471.36 72.520 253.060 3807.31 3879.28 2619.00 N 4896.37 W 6002500.50 N 560708.24 E 6.020 5007.21 7544.35 74.110 249.420 3828.27 3900.24 2596.51 N 4962.56 W 6002477.43 N 560642.26 E 5.250 5072.34 7594.30 72.820 246.940 3842.48 3914.45 2578.71 N 5007.01 W 6002459.25 N 560597.97 E 5.415 5115.96 7639.50 72.780 237.520 3855.88 3927.85 2558.62 N 5045.16 W 6002438.82 N 560559.99 E 19.907 5153.19 7687.76 78.380 230.940 3867.90 3939.87 2531.30 N 5083.03 W 6002411.17 N 560522.37 E 17.574 5189.81 ~ 7734.59 84.750 227.850 3874.77 3946.74 2501.16 N 5118.17W 6002380.72 N 560487.49 E 15.086 5223.59 7785.25 85.310 228.720 3879.16 3951.13 2467.58 N 5155.84 W 6002346.81 N 560450.11 E 2.037 5259.74 7831.97 87.400 227.800 3882.13 3954.10 2436.54 N 5190.63 W 6002315.47 N 560415.60 E 4.886 5293.13 7870.48 89.630 227.760 3883.13 3955.10 2410.67 N 5219.14 W 6002289.35 N 560387.32 E 5.792 5320.46 7926.65 92.660 227.250 3882.01 3953.98 2372.74 N 5260.54 W 6002251.06 N 560346.25 E 5.470 5360.15 7975.57 91.970 228.000 3880.03 3952.00 2339.80 N 5296.65 W 6002217.80 N 560310.43 E 2.082 5394.77 8020.33 91.790 227.100 3878.56 3950.53 2309.60 N 5329.66 W 6002187.31 N 560277.69 E 2.049 5426.42 8069.62 92.960 225.070 3876.52 3948.49 2275.45 N 5365.13 W 6002152.85 N 560242.52 E 4.750 5460.35 8116.64 92.900 224.410 3874.12 3946.09 2242.09 N 5398.19 W 6002119.20 N 560209.76 E 1.408 5491.90 8167.36 92.280 224.750 3871.82 3943.79 2206.00 N 5433.75 W 6002082.80 N 560174.51 E 1.394 5525.83 8213.45 92.970 225.770 3869.71 3941.68 2173.60 N 5466.45 W 6002050.11 N 560142.10 E 2.670 5557.07 8261.59 91.980 225.240 3867.63 3939.60 2139.89 N 5500.76 W 6002016.10 N 560108.09 E 2.332 5589.86 8308.62 90.680 223.960 3866.54 3938.51 2106.41 N 5533.77 W 6001982.34 N 560075.37 E 3.879 5621.36 8357.70 91.170 224.330 3865.75 3937.72 2071.20 N 5567.95 W 6001946.83 N 560041.50 E 1.251 5653.95 8404.62 89.140 224.690 3865.62 3937.59 2037.74 N 5600.84 W 6001913.08 N 560008.91 E 4.394 5685.33 8453.63 87.650 223.810 3867.00 3938.97 2002.65 N 5635.03 W 6001877.69 N 559975.03 E 3.530 5717.93 8500.03 87.470 223.330 3868.97 3940.94 1969.06 N 5666.98 W 6001843.82 N 559943.38 E 1.104 5748.37 8548.60 89.440 223.860 3870.28 3942.25 1933.90 N 5700.46 W 6001808.37 N 559910.21 E 4.200 5780.27 "- 8596.12 90.190 223.670 3870.43 3942.40 1899.58 N 5733.32 W 6001773.76 N 559877.65 E 1.628 5811.59 8644.22 88.330 224.800 3871.06 3943.03 1865.13 N 5766.87 W 6001739.01 N 559844.40 E 4.524 5843.58 8690.02 88.580 224.080 3872.29 3944.26 1832.44 N 5798.93 W 6001706.04 N 559812.63 E 1.664 5874.17 8739.68 89.010 224.380 3873.33 3945.30 1796.86 N 5833.56 W 6001670.16 N 559778.31 E 1.056 5907.19 8786.32 89.140 224.970 3874.09 3946.06 1763.70 N 5866.35 W 6001636.72 N 559745.82 E 1.295 5938.49 8837.17 88.150 225.040 3875.29 3947.26 1727.76 N 5902.30 W 6001600.46 N 559710.19 E 1.952 5972.81 8883.14 91.670 221.810 3875.36 3947.33 1694.38 N 5933.89 W 6001566.81 N 559678.89 E 10.392 6002.90 8935.35 91.300 219.740 3874.01 3945.98 1654.86 N 5967.97 W 6001526.99 N 559645.16 E 4.026 6035.21 8979.51 91.970 217.230 3872.75 3944.72 1620.31 N 5995.44 W 6001492.20 N 559617.99 E 5.881 6061.12 9029.92 92.590 216.150 3870.74 3942.71 1579.92 N 6025.54 W 6001451.54 N 559588.25 E 2.469 6089.40 9075.30 93.400 215.720 3868.37 3940.34 1543.23 N 6052.13 W 6001414.62 N 559561.98 E 2.020 6114.35 8 July, 2003 - 15:31 Page 4 of6 Dri/lQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Milne PoInt MPS . MPS-32 Your Ref: API 500292315700 Job No. AKZZ0002500145, Surveyed: 26 June, 2003 BP EXPLORA TION (ALASKA) INC. BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9126.26 94.510 215.540 3864.86 3936.83 1501.91 N 6081.75 W 6001373.04 N 559532.73 E 2.206 6142.12 9171.83 93.520 215.760 3861.67 3933.64 1464.97 N 6108.24 W 6001335.87 N 559506.56 E 2.225 6166.95 9224.77 92.100 215.660 3859.07 3931.04 1422.03 N 6139.10W 6001292.67 N 559476.08 E 2.689 6195.89 9268.08 92.410 215.900 3857.37 3929.34 1386.92 N 6164.41 W 6001257.34 N 559451.09 E 0.905 6219.62 9317.32 91.050 216.640 3855.88 3927.85 1347.24 N 6193.52 W 6001217.40 N 559422.32 E 3.144 6246.96 '- 9363.77 90.370 217.640 3855.30 3927.27 1310.22 N 6221.56 W 6001180.13 N 559394.60 E 2.603 6273.34 '- 9413.34 90.560 216.960 3854.90 3926.87 1270.79 N 6251.60 W 6001140.44 N 559364.91 E 1.424 6301.60 9459.72 88.830 217.410 3855.15 3927.12 1233.84 N 6279.63 W 6001103.25 N 559337.21 E 3.854 6327.98 9509.67 88.460 217.430 3856.33 3928.30 1194.18 N 6309.98 W 6001063.32 N 559307.21 E 0.742 6356.54 9555.67 90.060 218.320 3856.92 3928.89 1157.88 N 6338.21 W 6001026.77 N 559279.30 E 3.980 6383.15 9606.22 91.050 218.110 3856.44 3928.41 1118.16 N 6369.48 W 6000986.78 N 559248.38 E 2.002 6412.63 9651.74 91.110 217.400 3855.58 3927.55 1082.18 N 6397.35 W 6000950.56 N 559220.83 E 1.565 6438.88 9702.75 91.730 217.430 3854.31 3926.28 1041.68 N 6428.33 W 6000909.78 N 559190.20 E 1.217 6468.05 9748.01 90.190 218.960 3853.55 3925.52 1006.11 N 6456.31 W 6000873.97 N 559162.54 E 4.796 6494.43 9803.52 90. 190 219.160 3853.37 3925.34 963.01 N 6491.29 W 6000830.57 N 559127.94 E 0.360 6527.47 9844.24 90.550 218.470 3853.11 3925.08 931.28 N 6516.81 W 6000798.62 N 559102.69 E 1.911 6551.57 9892.75 92.780 219.310 3851.70 3923.67 893.54 N 6547.25 W 6000760.61 N 559072.59 E 4.912 6580.32 9939.95 92.900 219.710 3849.36 3921.33 857.17 N 6577.25 W - 6000723.98 N 559042.92 E 0.884 6608.67 9990.09 93.520 220.560 3846.55 3918.52 818.90 N 6609.52 W 6000685.42 N 559010.98 E 2.096 6639.22 10034.53 95.010 219.970 3843.25 3915.22 785.09 N 6638.16 W 6000651.36 N 558982.64 E 3.605 6666.34 10085.14 95.070 219.100 3838.80 3910.77 746.21 N 6670.25 W 6000612.20 N 558950.89 E 1.716 6696.69 10131.73 93.270 219.230 3835.41 3907.38 710.18 N 6699.59 W 6000575.91 N 558921.86 E 3.873 6724.41 10177.19 92.160 219.230 3833.26 3905.23 675.01 N 6728.31 W 6000540.49 N 558893.46 E 2.442 6751.55 10224.49 92.530 218.870 3831.32 3903.29 638.30 N 6758.09 W 6000503.53 N 558864.01 E 1.091 6779.67 - 10278.53 91.540 219.000 3829.41 3901.38 596.30 N 6792.02 W 6000461.22 N 558830.44 E 1.848 6811.73 10320.25 91.360 219.050 3828.35 3900.32 563.89 N 6818.29 W 6000428.59 N 558804.46 E 0.448 6836.53 10373.92 92.040 218.680 3826.76 3898.73 522.12 N 6851.95 W 6000386.53 N 558771.17 E 1.442 6868.32 10420.35 91.730 217.930 3825.23 3897.20 485.71 N 6880.71 W 6000349.86 N 558742.73 E 1.747 6895.44 10469.89 94.330 217.600 3822.61 3894.58 446.61 N 6911.01 W 6000310.49 N 558712.78 E 5.290 6923.98 10515.24 93.700 216.890 3819.44 3891.41 410.59 N 6938.38 W 6000274.24 N 558685.72 E 2.090 6949.75 10566.68 95.310 215.770 3815.40 3887.37 369.28 N 6968.76 W 6000232.66 N 558655.70 E 3.809 6978.27 10612.90 95.930 215.150 3810.87 3882.84 331.82 N 6995.45 W 6000194.97 N 558629.35 E 1.892 7003.28 10679.00 95.930 215.150 3804.04 3876.01 278.06 N 7033.30 W 6000140.88 N 558591.97 E 0.000 7038.72 Projected Survey 8 July, 2003 - 15:31 Page 5 of6 Drif/Quest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-32 Your Ref: APlS00292315700 Job No. AKZZ0002500145, Surveyed: 26 June, 2003 BP EXPLORA TfON (ALASKA) INC. Milne Point Unit BPXA All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 272.530° (True). Magnetic Declination at Surface is 25.46r(18-Jun-03) '- Based upon Minimum Curvature type calculations, at a Measured Depth of 10679.00ft., The Bottom Hole Displacement is 7038.80ft., in the Direction of 272.264° (True). .~ Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 10679.00 3876.01 278.06 N 7033.30 W Projected Survey Survey tool proqram for MPS-32 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) - 0.00 641.00 0.00 641.00 640.15 10679.00 640.15 Tolerable Gyro (MPS-32 GYRO) 3876.01 AK-6 BP _IFR-AK (MPS-32) 8 July, 2003 - 15:31 Page 60f6 DrillQuest 3.03.02.005 ) AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 ) 15-Jul-03 Re: Distribution of Survey Data for Well MPS-32 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window I Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 10,679.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) á03 --DC¡ ~ RECEIVED JUa, 1 6 2003 Alaska Ott & Gas Cons. Commieeion n ~d1omgeAd ^ d {'f/L-(;L£¡....., I~ ~d- Sperry-Sun Drilling Services Milne Point Unit BPXA Milne Point MPS MPS-32 MWD ~' Job No. AKMW0002500145, Surveyed: 26 June, 2003 Survey Report 8 July, 2003 Your Ref: AP/SO0292315700 Surface Coordinates: 5999924.63 N, 565627.44 E (70024' 36.8661" N, 149027' 56.2179" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 -' Surface Coordinates relative to Project H Reference: 999924.63 N, 65627.44 E (Grid) Surface Coordinates relative to Structure: 44.06 S, 717.97 W (True) Kelly Bushing: 71.97ft above Mean Sea Level Elevation relative to Project V Reference: 71.97ft Elevation relative to Structure: 71.97ft spe""r'y-sul! DRILLING SERVices A Halliburton Company Sutvey Ref: svy1222 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-32 MWD Your Ref: AP/500292315700 Job No. AKMW0002500145, Surveyed: 26 June, 2003 BP EXPLORA TION (ALASKA) INC. BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 641 .00 7.700 326.000 568.18 640.15 21.53 N 11.65 W 5999946.06 N 565615.60 E 12.59 MWO Magnetic 759.99 10.260 331.230 685.71 757.68 37.43 N 21.21 W 5999961.87 N 565605.90 E 2.256 22.84 853.71 14.250 320.980 777.28 849.25 53.72 N 32.50 W 5999978.06 N 565594.47 E 4.833 34.84 951.01 18.960 315.660 870.50 942.47 74.34 N 51.10W 5999998.52 N 565575.69 E 5.082 54.33 1046.71 24.530 310.570 959.37 1031.34 98.40 N 77.07 W 6000022.35 N 565549.50 E 6.140 81.34 1141.76 26.610 312.480 1045.10 1117.07 125.61 N 107.77 W 6000049.29 N 565518.57 E 2.354 113.21 .--- 1237.69 27.590 312.980 1130.50 1202.47 155.27 N 139.86 W 6000078.66 N 565486.22 E 1.049 146.58 1333.80 29.020 313.030 1215.12 1287.09 186.35 N 173.19 W 6000109.45 N 565452.62 E 1.488 181.25 1429.23 31.450 309.560 1297.57 1369.54 218.01 N 209.31 W 6000140.79 N 565416.22 E 3.135 218.73 1525.23 35.580 307.220 1377 .59 1449.56 250.87 N 250.88 W 6000173.28 N 565374.37 E 4.507 261.71 1621.48 36.300 309.090 1455.52 1527.49 285.77 N 295.29 W 6000207.79 N 565329.65 E 1.364 307.62 1718.37 37.580 307.030 1532.96 1604.93 321.65 N 341.14 W 6000243.27 N 565283.49 E 1.838 355.01 1814.98 38.830 311.360 1608.89 1680.86 359.41 N 387.40 W 6000280.63 N 565236.89 E 3.058 402.89 1911.25 42.430 309.840 1681.94 1753.91 400.18 N 435.01 W 6000320.97 N 565188.93 E 3.878 452.25 2006.90 42.790 310.620 1752.34 1824.31 442.00 N 484.45 W 6000362.36 N 565139.13 E 0.668 503.48 2101.17 43.420 310.600 1821.17 1893.14 483.93 N 533.35 W 6000403.86 N 565089.86 E 0.668 554.19 2197.60 46.060 309.330 1889.66 1961.63 527.51 N 585.38 W 6000446.98 N 565037.45 E 2.890 608.09 2292.55 49.930 308.830 1953.19 2025.16 571.97 N 640.14 W . 6000490.96 N 564982.30 E 4.095 664.77 2389.07 54.430 306.640 2012.36 2084.33 618.58 N 700.45 W 6000537.03 N 564921.59 E 4.994 727.07 2484.33 58.840 301.800 2064.76 2136.73 663.22 N 766.23 W 6000581.09 N 564855.41 E 6.278 794.76 2580.41 63.840 301.690 2110.82 2182.79 707.56 N 837.91 W 6000624.80 N 564783.35 E 5.205 868.32 2676.50 65.140 304.110 2152.21 2224.18 754.67 N 910.71 W 6000671.27 N 564710.14 E 2.645 943.13 2772.94 67.570 303.420 2190.89 2262.86 803.76 N 984.15 W 6000719.72 N 564636.27 E 2.604 1018.67 2867.26 69.080 303.980 2225.72 2297.69 852.40 N 1057.06 W 6000767.71 N 564562.93 E 1.693 1093.66 ~ 2963.91 70.940 301.920 2258.77 2330.74 901.79 N 1133.28 W 6000816.42 N 564486.28 E 2.778 1171.98 3059.41 72.570 302.050 2288.66 2360.63 949.83 N 1210.20 W 6000863.79 N 564408.94 E 1.712 1250.95 3120.14 70.620 303.650 2307.84 2379.81 981.08 N 1258.61 W 6000894.61 N 564360.26 E 4.069 1300.69 3246.28 69.390 301.830 2350.97 2422.94 1045.19 N 1358.31 W 6000957.84 N 564260.00 E 1.670 1403.12 3343.21 69.300 300.690 2385.17 2457.14 1092.25 N 1435.84 W 6001004.22 N 564182.06 E 1.104 1482.65 3438.54 70.040 301.31 0 2418.29 2490.26 1138.29 N 1512.46 W 6001049.59 N 564105.04 E 0.987 1561.23 3533.71 69.750 297.670 2451.01 2522.98 1182.28 N 1590.23 W 6001092.89 N 564026.88 E 3.604 1640.87 3629.90 69.300 300.270 2484.66 2556.63 1225.92 N 1669.06 W 6001135.84 N 563947.67 E 2.575 1721.55 3725.85 69.170 299.620 2518.68 2590.65 1270.70 N 1746.80 W 6001179.94 N 563869.54 E 0.648 1801.19 3822.03 68.660 301.730 2553.28 2625.25 1316.48 N 1823.98 W 6001225.03 N 563791.96 E 2.114 1880.32 3919.17 69.120 302.910 2588.27 2660.24 1364.93 N 1900.56 W 6001272.81 N 563714.96 E 1.228 1958.96 ---- ------------- 8 July, 2003 - 15:33 Page 20f6 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for MIlne PoInt MPS . MPS·32 MWD Your Ref: API 500292315700 Job No. AKMW0002500145, Surveyed: 26 June, 2003 BP EXPLORA nON (ALASKA) INC. BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 4016.48 68.440 301.350 2623.49 2695.46 1413.18N 1977.37 W 6001320.38 N 563637.72 E 1.650 2037.83 4112.41 68.000 302.990 2659.09 2731.06 1460.60 N 2052.78 W 6001367.14 N 563561.91 E 1.652 2115.25 4208.73 68.580 302.030 2694.72 2766.69 1508.69 N 2128.24 W 6001414.57 N 563486.02 E 1.105 2192.76 4302.59 69.110 303.730 2728.60 2800.57 1556.22 N 2201.75 W 6001461.44 N 563412.10 E 1.781 2268.30 4398.62 70.170 303.030 2762.01 2833.98 1605.75 N 2276.93 W 6001510.31 N 563336.49 E 1.298 2345.59 4495.19 71.210 299.080 2793.95 2865.92 1652.74 N 2354.99 W 6001556.61 N 563258.02 E 4.007 2425.65 .~ 4591.53 69.710 299.750 2826.17 2898.14 1697.33 N 2434.07 W 6001600.50 N 563178.55 E 1.689 2506.62 4687.35 69.380 300.600 2859.66 2931.63 1742.45 N 2511.69 W 6001644.95 N 563100.54 E 0.900 2586.15 4782.71 69.390 303.190 2893.24 2965.21 1789.61 N 2587.46 W 6001691.43 N 563024.36 E 2.542 2663.93 4878.80 69.570 301.660 2926.92 2998.89 1837.86 N 2663.42 W 6001739.01 N 562947.98 E 1.503 2741.95 4975.64 69.240 302.490 2960.99 3032.96 1885.99 N 2740.23 W 6001786.47 N 562870.75 E 0.872 2820.81 5070.77 69.910 302.830 2994.19 3066.16 1934.10 N 2815.28 W 6001833.92 N 562795.27 E 0.780 2897.91 5167.27 70.110 301.410 3027.18 3099.15 1982.32 N 2892.08 W 6001881.46 N 562718.05 E 1.398 2976.77 5263.84 69.310 301. 120 3060.66 3132.63 2029.33 N 2969.51 W 6001927.79 N 562640.22 E 0.875 3056.19 5360.17 69.700 301.070 3094.39 3166.36 2075.93 N 3046.77 W 6001973.71 N 562562.54 E 0.408 3135.44 5456.21 69.570 301.500 3127.81 3199.78 2122.69 N 3123.72 W 6002019.79 N 562485.19 E 0.441 3214.37 5552.88 69.970 300.850 3161.24 3233.21 2169.64 N 3201.33 W 6002066.06 N 562407.17 E 0.754 3293.98 5649.03 71.020 301.380 3193.35 3265.32 2216.47 N 3278.92 W . 6002112.21 N 562329.17 E 1.209 3373.56 5745.35 69.250 301.160 3226.07 3298.04 2263.50 N 3356.34 W 6002158.55 N 562251.34 E 1.850 3452.99 5841 .18 69.450 302.210 3259.87 3331.84 2310.60 N 3432.65 W 6002204.97 N 562174.62 E 1.046 3531.30 5937.36 69.830 303.190 3293.33 3365.30 2359.31 N 3508.53 W 6002253.02 N 562098.32 E 1.034 3609.25 6033.78 68.960 302.510 3327.27 3399.24 2408.27 N 3584.34 W 6002301.31 N 562022.07 E 1.118 3687.16 6130.02 69.840 299.130 3361.14 3433.11 2454.41 N 3661.70 W 6002346.77 N 561944.32 E 3.412 3766.47 6225.73 70.360 298.780 3393.71 3465.68 2497.97 N 3740.44 W 6002389.64 N 561865.19 E 0.643 3847.06 -- 6321.69 71.460 297.920 3425.10 3497.07 2541.03 N 3820.25 W 6002432.00 N 561785.01 E 1.425 3928.69 6418.64 72.510 295.000 3455.09 3527.06 2582.10 N 3902.78 W 6002472.34 N 561702.12 E 3.062 4012.96 6512.96 72.190 292.280 3483.69 3555.66 2618.14 N 3985.11 W 6002507.65 N 561619.48 E 2.769 4096.79 6608.13 69.970 288.780 3514.55 3586.52 2649.72 N 4069.39 W 6002538.49 N 561534.92 E 4.188 4182.39 6703.80 69.700 287.010 3547.54 3619.51 2677.32 N 4154.85 W 6002565.33 N 561449.23 E 1.759 4268.98 6799.88 69.310 283.840 3581.18 3653.15 2701.25 N 4241.59 W 6002588.51 N 561362.28 E 3.117 4356.69 6895.73 71 .140 277.580 3613.64 3685.61 2717.98 N 4330.16 W 6002604.45 N 561273.56 E 6.435 4445.92 6991 . 17 72.310 270.660 3643.60 3715.57 2724.46 N 4420.49 W 6002610.15 N 561183.18 E 6.993 4536.44 7086.76 71.140 264.650 3673.60 3745.57 2720.77 N 4511.13 W 6002605.65 N 561092.58 E 6.094 4626.83 7183.26 70.160 259.740 3705.59 3777.56 2708.42 N 4601.30 W 6002592.51 N 561002.52 E 4.907 4716.37 7280.38 67.700 259.330 3740.50 3812.47 2691.96 N 4690.41 W 6002575.27 N 560913.55 E 2.563 4804.67 -- 8 July, 2003 - 15:33 Page 3 of6 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services SUlVey Report for Milne Point MPS - MPS-32 MWD Your Ref: API 500292315700 Job No. AKMW0002500145, SUlVeyed: 26 June, 2003 BP EXPLORA TlON (ALASKA) INC. BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 7377.44 68.920 258.230 3776.38 3848.35 2674.41 N 4778.87 W 6002556.95 N 560825.25 E 1.640 4892.27 7471.36 72.520 252.920 3807.40 3879.37 2652.30 N 4864.67 W 6002534.08 N 560739.65 E 6.569 4977.01 7544.35 74.110 92.360 3856.02 3927.99 2625.22 N 4860.50 W 6002507.04 N 560744.06 E 193.891 4971.65 7594.30 72.820 247.450 3887.24 3959.21 2602.95 N 4856.19 W 6002484.81 N 560748.57 E 277.897 4966.35 7639.50 72.780 237.230 3900.64 3972.61 2582.94 N 4894.37 W 6002464.46 N 560710.56 E 21.597 5003.62 7687.76 78.380 231.210 3912.67 3984.64 2555.61 N 4932.24 W 6002436.80 N 560672.94 E 16.747 5040.24 -~ 7734.59 84.750 228.360 3919.53 3991.50 2525.71 N 4967.58 W 6002406.59 N 560637.86 E 14.874 5074.23 7785.25 85.310 229.170 3923.92 3995.89 2492.44 N 5005.54 W 6002373.00 N 560600.20 E 1.939 5110.68 7831.97 87.400 228.260 3926.89 3998.86 2461.68 N 5040.57 W 6002341.93 N 560565.43 E 4.877 5144.32 7870.48 89.630 228.230 3927.89 3999.86 2436.05 N 5069.29 W 6002316.04 N 560536.94 E 5.791 5171.88 7926.65 92.660 227.590 3926.77 3998.74 2398.41 N 5110.96 W 6002278.04 N 560495.61 E 5.513 5211.85 7975.57 91.970 228.540 3924.79 3996.76 2365.74 N 5147.32 W 6002245.05 N 560459.53 E 2.399 5246.73 8020.33 91.790 227.670 3923.32 3995.29 2335.87 N 5180.62 W 6002214.89 N 560426.50 E 1.984 5278.68 8069.62 92.960 226.120 3921.28 3993.25 2302.22 N 5216.57 W 6002180.92 N 560390.84 E 3.938 5313.11 8116.64 92.900 225.820 3918.88 3990.85 2269.58 N 5250.34 W 6002147.99 N 560357.37 E 0.650 5345.40 8167.36 92.280 225.950 3916.58 3988.55 2234.31 N 5286.71 W 6002112.40 N 560321.30 E 1.249 5380.19 8213.45 92.970 226.130 3914.47 3986.44 2202.35 N 5319.85 W 6002080.15 N 560288.44 E 1.547 5411.89 8261.59 91.980 225.690 3912.39 3984.36 2168.89 N 5354.40 W 6002046.39 N 560254.19 E 2.250 5444.92 8308.62 90.680 224.570 3911.30 3983.27 2135.72 N 5387.72 W 6002012.93 N 560221.16 E 3.648 5476.74 8357.70 91.170 225.290 3910.51 3982.48 2100.98 N 5422.37 W 6001977.88 N 560186.81 E 1.774 5509.83 8404.62 89.140 225.120 3910.38 3982.35 2067.92 N 5455.67 W 6001944.53 N 560153.81 E 4.342 5541.63 8453.63 87.650 224.660 3911.76 3983.73 2033.21 N 5490.24 W 6001909.52 N 560119.54 E 3.182 5574.64 8500.03 87.470 224.160 3913.73 3985.70 2000.10 N 5522.68 W 6001876.12 N 560087.40 E 1.144 5605.59 8548.60 89.440 224.710 3915.04 3987.01 1965.43 N 5556.67 W 6001841.16 N 560053.71 E 4.211 5638.02 - 8596.12 90.190 224.470 3915.19 3987.16 1931.59 N 5590.03 W 6001807.03 N 560020.65 E 1.657 5669.85 8644.22 88.330 225.870 3915.82 3987.79 1897.68 N 5624.14 W 6001772.82 N 559986.84 E 4.840 5702.43 8690.02 88.580 224.530 3917.05 3989.02 1865.42 N 5656.63 W 6001740.28 N 559954.64 E 2.975 5733.46 8739.68 89.010 225.020 3918.10 3990.07 1830.18 N 5691.60 W 6001704.73 N 559919.98 E 1.313 5766.84 8786.32 89.140 225.120 3918.85 3990.82 1797.24 N 5724.61 W 6001671.50 N 559887.26 E 0.352 5798.37 8837.17 88. 150 226.190 3920.05 3992.02 1761.71 N 5760.96 W 6001635.65 N 559851.22 E 2.866 5833.12 8883.14 91.670 221.860 3920.12 3992.09 1728.67 N 5792.90 W 6001602.33 N 559819.57 E 12.138 5863.56 8935.35 91.300 219.850 3918.77 3990.74 1689.20 N 5827.04 W 6001562.56 N 559785.78 E 3.913 5895.92 8979.51 91.970 217.370 3917.51 3989.48 1654.71 N 5854.58 W 6001527.83 N 559758.54 E 5.815 5921.92 9029.92 92.590 216.310 3915.50 3987.47 1614.40 N 5884.78 W 6001487.25 N 559728.70 E 2.435 5950.31 9075.30 93.400 215.580 3913.13 3985.10 1577.71 N 5911.38 W 6001450.33 N 559702.42 E 2.401 5975.27 8 July, 2003 - 15:33 Page 4 of6 DríllQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Milne Point MPS . MPS-32 MWD Your Ref: API 500292315700 Job No. AKMW0002500145, Surveyed: 26 June, 2003 BP EXPLORA TlON (ALASKA) INC. BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9126.26 94.510 215.470 3909.62 3981.59 1536.33 N 5940.92 W 6001408.70 N 559673.25 E 2.189 6002.95 9171.83 93.520 215.800 3906.43 3978.40 1499.39 N 5967.41 W 6001371.52 N 559647.09 E 2.289 6027.78 9224.77 92.100 215.530 3903.83 3975.80 1456.43 N 5998.24 W 6001328.30 N 559616.64 E 2.730 6056.68 9268.08 92.410 216.370 3902.13 3974.10 1421.40 N 6023.64 W 6001293.04 N 559591.54 E 2.066 6080.52 9317.32 91.050 216.900 3900.64 3972.61 1381.90 N 6053.01 W 6001253.29 N 559562.52 E 2.964 6108.11 9363.77 90.370 217.560 3900.07 3972.04 1344.92 N 6081.11 W 6001216.07 N 559534.74 E 2.040 6134.55 --' 9413.34 90.560 217.010 3899.66 3971.63 1305.48 N 6111.14 W 6001176.37 N 559505.06 E 1.174 6162.81 9459.72 88.830 217.960 3899.91 3971.88 1268.68 N 6139.36 W 6001139.32 N 559477.17 E 4.255 6189.38 9509.67 88.460 217.970 3901.09 3973.06 1229.31 N 6170.08 W 6001099.68 N 559446.79 E 0.741 6218.33 9555.67 90.060 219.070 3901.69 3973.66 1193.33 N 6198.73 W 6001063.45 N 559418.47 E 4.221 6245.36 9606.22 91.050 218.710 3901.20 3973.17 1153.99 N 6230.46 W 6001023.82 N 559387.08 E 2.084 6275.33 9651.74 91.110 218.040 3900.34 3972.31 1118.31 N 6258.72 W 6000987.90 N 559359.14 E 1.478 6301.98 9702.75 91.730 217.660 3899.07 3971.04 1078.04 N 6290.01 W 6000947.36 N 559328.20 E 1.425 6331.46 9748.01 90.190 219.390 3898.32 3970.29 1042.64 N 6318.19 W 6000911.71 N 559300.33 E 5.117 6358.06 9803.52 90.190 219.790 3898.13 3970.10 999.86 N 6353.57 W 6000868.63 N 559265.33 E 0.721 6391.51 9844.24 90.550 219.210 3897.87 3969.84 968.44 N 6379.47 W 6000836.98 N 559239.71 E 1.676 6416.00 9892.75 92.780 220.110 3896.46 3968.43 931.12 N 6410.41 W 6000799.38 N 559209.09 E 4.957 6445.26 9939.95 92.900 220.350 3894.12 3966.09 895.12 N 6440.86 W . 6000763.13 N 559178.97 E 0.568 6474.09 9990.09 93.520 221.430 3891.31 3963.28 857.28 N 6473.63 W 6000724.99 N 559146.53 E 2.481 6505.16 10034.53 95.010 221.200 3888.01 3959.98 824.00 N 6502.89 W 6000691.45 N 559117.57 E 3.392 6532.92 10085.14 95.070 219.910 3883.56 3955.53 785.69 N 6535.66 W 6000652.86 N 559085.13 E 2.542 6563.97 10131.73 93.270 220.300 3880.17 3952.14 750.15 N 6565.60 W 6000617.06 N 559055.51 E 3.953 6592.31 10177.19 92.160 220.240 3878.02 3949.99 715.51 N 6594.95 W 6000582.16 N 559026.46 E 2.445 6620.10 10224.49 92.530 219.660 3876.09 3948.06 679.28 N 6625.29 W 6000545.67 N 558996.43 E 1.454 6648.82 ~ 10278.53 91.540 219.430 3874.17 3946.14 637.63 N 6659.68 W 6000503.72 N 558962.42 E 1.881 6681.33 10320.25 91.360 219.530 3873.11 3945.08 605.44 N 6686.19 W 6000471.30 N 558936.18 E 0.494 6706.40 10373.92 92.040 218.910 3871.52 3943.49 563.88 N 6720.12 W 6000429.44 N 558902.63 E 1.714 6738.46 10420.35 91.730 218.110 3869.99 3941.96 527.57 N 6749.01 W 6000392.88 N 558874.06 E 1.847 6765.72 10469.89 94.330 217.830 3867.37 3939.34 488.57 N 6779.44 W 6000353.61 N 558843.97 E 5.279 6794.40 10515.24 93.700 217.210 3864.20 3936.17 452.69 N 6806.99 W 6000317.49 N 558816.73 E 1.947 6820.34 10566.68 95.310 215.850 3860.16 3932.13 411.49 N 6837.52 W 6000276.02 N 558786.57 E 4.092 6849.02 10612.90 95.930 215.280 3855.63 3927.60 374.07 N 6864.27 W 6000238.37 N 558760.15 E 1.818 6874.09 10679.00 95.930 215.280 3848.80 3920.77 320.40 N 6902.25 W 6000184.37 N 558722.65 E 0.000 6909.66 Projected Survey --- 8 July. 2003 - 15:33 Page 5 of6 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Milne Point MPS · MPS-32 MWD Your Ref: API 500292315700 Job No. AKMW0002500145, Surveýed: 26 June, 2003 BP EXPLORA TION (ALASKA) INC. Milne Point Unit BPXA All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 272.530° (True). Magnetic Declination at Surface is 25.46r(18-Jun-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 10679.000., The Bottom Hole Displacement is 6909.68ft., in the Direction of 272.658° (True). ~. Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings ~) ~ ~ Comment 10679.00 3920.77 320.40 N 6902.25 W Projected Survey Survey tool proqram for MPS-32 MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) .--- 0.00 641.00 0.00 640.15 641.00 10679.00 640.15 Tolerable Gyro (MPS-32 GYRO) 3920.77 MWD Magnetic (MPS-32 MWD) 8 July, 2003 - 15:33 Page 60f6 DrillQuest 3.03.02.005 '~ ! ) (QJ l-"-rffi~íl rE ,.~\ I ' ¡! t~) J l L,' lÇ J~ fÆLfÆ~:~!Æ FRANK H. MURKOWSKI, GOVERNOR A.IIA.~1iA. OIL AIft) GAS CONSERVATION COMMISSION 333 W. "fTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 P at Archey Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Milne Point Unit J\t1PS-32 BP Exploration (Alaska), Inc. Permit No: 203-092 Surface Location: 3259' NSL, 383' WEL, Sec. 12, TI2N, RI0E, UM Bottomhole Location: 3567' NSL, 2161' WEL, Sec. 11, TI2N, RI0E, UM Dear Mr. Archey: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). SinCerelY., /J.. ~ ¡(uP {~~ ~ Randy ;2driCh Commissioner BY ORDER OF THE COMMISSION DATED this 2ß day of May, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section Hole 42" 13-1/2" 9-718" 6-1/8" ) STATE OF ALASKA \ ALASKAulL AND GAS CONSERVATION COMfv.._.lSION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well D Exploratory ÇL2tratigraphic Test a Development Oil D Service D Development Gas ~ Single Zone Þ () D Multiple Zone 5. Datum Elevation (OF or KB) 10. Field and Pool Planned KBE = 72' Milne Point Unit / Schrader 6. Property Designation Bluff ADL 380109 7. Unit or Property Name Milne Point Unit 8. Well Number MPS-32 9. Approximate spud date 06-10-03 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 10672' MD / 3882' TVD o 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 97 Maximum surface 1291 psig, At total depth (TVD) 3865' / 1678 psig Setting Depth Top Bottom MD TVD MD TVD Surface Surface 112' 112' Surface Surface 3105' 2382' Surface Surface 7557' 3937' 7457' 3908' 10672' 3882' 4JÐ 1 a. Type of work a Drill D Redrill D Re-Entry D Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface x = 565627, Y = 5999925 3259' NSL, 383' WEL, SEC. 12, T12N, R10E, UM At top of productive interval x = 560675, Y = 6002445 542' NSL, 34' WEL, SEC. 02, T12N, R10E, UM At total depth x = 558568, Y = 6000175 3567' NSL, 2161' WEL, SEC. 11, T12N, R10E, UM 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 12. Distance to nearest property line 13. Distance to nearest well ADL 025627,3319' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 300' MD Maximum Hole Angle 18. Casing Program Spec'f' t· Size I Ica Ions Casina Weiaht Grade CouDlina 20" 92# H-40 Weld 10-3/4" 45.5# L-80 BTC 7-5/8" 29.7# L-80 BTC 4-1/2" 12.7# L-80 BTC Lenath 112' 3105' 7557' 3215' Quantity of Cement (include staae data) 260 sx Arctic Set (Approx.) 688 SX PF 'L', 261 sx Class 'G' 426 sx Class 'G' Uncemented Slotted Liner 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD Perforation depth: measured RECEIVED MAY 1 5 2003 Alaska Oil & Gas Cons. Commission Anchorage true vertical 20. Attachments a Filing Fee D Property Plat D BOP Sketch D Diverter Sketch a Drilling Program a Drilling Fluid Program D Time vs Depth Plot D Refraction Analysis D Seabed Report D 20 AAC 25.050 Requirements Contact Engineer Name/Number: Matt Green, 564-5581 Prepared By Name/Number: Sandra Stewman, 564-4750 21. I hereby certify that the~orego~ is t>fe and correct to the best of my knowledge Signed Pat Archey r 3 ~d Title Senior Drilling Engineer A', Commission Use Only' Permit Number 3' 9 2- API Number ,-7 ApRJO~~1 ate :2.D -D 50- 1:J2Q'-;Lôl':::>-(x:) J¡../-AJ 0 -:s Conditions of Approval: Samples Required 0 Yes ~No Mud Log Req ired Hydrogen Sulfide Measures 0 Yes .BfNo Directional Survey Required Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K Other: ~5ÖO 'fS \ ~a? -H:s ~ by order of ~~:'~o~~~~ Rev. 12-;:;; ¿{7 ~-/4" ü-R YGil!~~r L the commission Date .s// y /Ó.3 See cover letter for other reauirements o Yes ~o ~es 0 No o 3.5K psi for CTU Date S/ ¿fj,¡'¿y(' ~m;t In ~ri~lidte I) 1\ )e Point MPS-32 Well Permit IWell Name: I MPS-32 Drill and Complete Plan Summary I Type of Well (service / producer / injector): I Single Lateral Producer "NB" Surface Location: 20211 FNL, (32591 FSL), 3831 FEL, (48961 FWL), SEC. 12, T12N,R1 OE E=565627.67 N=5999924.61 4738' FNL, (5421 FSL), 34' FEL, (52451 FWL), SEC. 2, T12N, R10E E=560675 N=6002445 Z=3865' TVDss 1712' FNL, (35671 FSL), 2161' FEL, (31191 FWL), SEC. 11, T12N,R1 OE E=558568 N=6000175 Z=3810' TVDss Target Location: TOP "NB" Target Location: BHL "NB" Well TD I AFE Number: I I Estimated Start Date: 110 Jun 2003 1 Rig: I Doyon 14 1 Operating days to complete: 115.9 I MD: 110,672 I 1 TVD: 13,882 1 I Max Inc: 197 1 I KOP: 1300 I I KBE:172 Well Design (conventional, slim hole, etc.): Conventional Grass Roots Lateral Producer I Objective: I Schrader NB Sand Mud Program: 13-1/2" Surface Hole Mud Properties: Density (ppg) Funnel visc VP HTHP 8.6 - 9.0 75 - 150 25 - 60 N/A Spud - LSND Freshwater Mud pH API Filtrate LG Solids 8.5 - 9.5 < 8 < 12 9-7/8" Intermediate Hole Mud Properties: Density (ppg) Funnel visc VP HTHP 9.0 - 9.3 75 - 150 25 - 60 N/A LSND Freshwater Mud pH API Filtrate LG Solids 9.0 - 9.5 < 8 < 12 6.125-in Production Hole Mud Properties: KCL-CaC03 Flo-Pro Density (ppg) Funnel visc VP HTHP pH API Filtrate LG Solids 8.6 - 10.0 40 - 55 22 - 27 <10 8.0 - 8.5 4 - 6 < 8 LCM Restrictions: No Organic LCM products in the Schrader Bluff formation Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to 08-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1 R. 1 , ) '\ ~ )e Point MPS-32 Well Permit Cement Program: CasinQ Size 110-3/4" 45.5-lb/ft L-80 BTC Surface Casing Basis 1250% excess over gauge hole in permafrost interval 400/0 excess over gauge hole below permafrost Total Cement Volume: 563-bbl Wash 20-bbl water Spacer Lead 50-bbl 1 0.2-lb/gal Alpha Spacer 509-bbl, 688-sx 10.7 Ib/gal Class L - 4.15 fe/sx (cement to surface) 54-bbl, 261-sx 15.8 Ib/gal Prem G - 1.15 ft::S/sx to of tail at 2,605-ft MD BHST ~ 55°F from SOR, BHCT 60°F estimated by Halliburton Tail Temp Casin~ Size 17-5/8 29.7-lb/ft L-80 BTC Intermediate Casing Basis 140% excess over gauge hole. Lead 500-ft MD above top of Ugnu. Total Cement Volume: 122-bbl Wash 5-bbl water Sp~cer Lead 30-bbl 1 0.2-lb/9..,....~........1 Alp.;",~a Sp~~~r (~lp,h~L . . 92.6-bbl, 426-sx 15.6·lb/g~I··P~e~··G~1"~·22fi3/sx· (top of lead at 5,900-ft MD) BHST ~ 80°F from SOR, BHCT 70°F estimated by Halliburton Temp Evaluation Program: 13-1/2" Section Open Hole: MWD/GR IFRlCASANDRA Gyro as required Cased Hole: N/A 9-7/8" Section Open Hole: MWD/GRlRES IFRlCASANDRA Cased Hole: N/A 6-1/8"Section Open Hole: MWD/GR/RES ABIIPWD IFRlCASANDRA 2 ) Formation Markers: Formation Tops Base Permafrost Top Ugnu Middle Ugnu NA NB MDrkb (ft) 2002 6400 6872 7481 7557 TVDrkb (ft) 1822 3542 3713 3915 3937 CasingITubing Program: Pore Pressure (psi) 760 1507 1581 1669 1678 1\\ Point MPS-32 Well Permit Estimated EMW (Ib/gal)* 8.35 8.35 8.35 8.35 8.35 Hole Csg/ WtlFt Grade Conn Length Top Bottom Size Tbg O.D. MD / TVDrkb MD / TVDrkb 42-in 20-in* 92# H-40 Weld 112' 0 112-ft / 112-ft 13-1 /2" 10-3/4" 45.5# L-80 BTC 3105' 0 3105' / 2382' 9-7/8" 7-5/8" 29.7# L-80 BTC 7557' 0 7557' / 3937' 6-1/8" 4-1 /2" 12.7# L-80 BTC 3215' 7457' / 3908' 1 0672'/ 3882' NB *The 20" casing is insulated Recommended Bit Program: BHA Hole Size 1 13-1 /2" 2 9-7/8" 3 6-1 /8" Depth (MD) 0-3105' 3105 - 7557' 7557' - TD Bit Type M ill tooth M ill tooth Security FM2643 3 Nozzle/Flow rate 3-15 & 1 -1 0 3-15 & 1 -1 0 3-12 ') 1\ .)e Point MPS-32 Well Permit Well Control: Surface Interval · The surface hole will be drilled with a diverter. · Integrity test: · Kick tolerance: Intermediate and Production Intervals · Maximum anticipated BHP: 1,678-psi @ 3,865-ft TVDss - Top of NB-sand · Maximum surface pressure: 1 ,291-psi @ surface (Based on BHP and a full column of gas from TD @ 0.1-psi/ft) · Planned BOP test pressure: Diverter will be function tested. BOPs: Test annular 250-psi low and 2,500-psi high, and rams to 250-psi low and 3,500-psi high. An FIT to 11.5-lb/gal will be made on the 7-5/8" casing shoe. 112.7-bbl with 9.2-lb/gal mud and FIT of 11.5-lb/gal @ 10-3/4" casing shoe. 9.2-lb/gal NaCI I 6.8-lb/gal Diesel · Planned completion fluid: Drilling Hazards & Contingencies: Hydrates · Hydrates have not been seen on S pad, but has been encountered in the surface holes on other pads, especially nearby H-Pad. Hydrates generally occur just below the Permafrost (+1- 1800 ss) but may be present in shallower SV sands and also as deep as 3000 ft. Be alert for the possibility of shallow gas and/or hydrates. Use recommended practices for drilling hydrates. Pretreat mud with DrilTreat; Increase mud wt; Maintain cool mud « 60 deg F); Limit ROP and Reduce pump rate while drilling hydrates; Circulate connections thoroughly. See Well Program and Recommended Practices for specific information. · Another item to watch out for is deeper gravels below the Permafrost or gravels that calve off within the permafrost and will tend to drop out when the aerated hydrate gas cut mud is being circulated out. Maintain adequate viscosity. In the past several Milne Pt wells have experienced stuck pipe from this situation. Lost Circulation · We do not expect losses while drilling this well. . Offset wells encountered losses while running and cementing casing and only one well had losses while running a hole opener. Below is a list of the wells and the lost circulating problems associated with them. H-06 (1995): Lost 100 bbls running 9-5/8" casing, good returns during cementing except no returns for last 20 bbls, contaminated cement to surface, cement 12 ft down, no top job. Follow the LOST CIRCULATION DECISION MATRIX in the well plan if fluid losses occur while drilling. Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing. Expected Pressures · It is unlikely there will be unexpected overpressure when drilling to the Schrader Bluff formation. Reservoir pressure is expected to be (8.35 Ib/gal EMW). 4 ) 1\ -k Point MPS-32 Well Permit Pad Data Sheet . Please Read the S-Pad Data Sheet thoroughly. Breathing · N/A Hydrocarbons · Hydrocarbons will be encountered in the NA through the Schrader Bluff. Faults · A 30 to 50-ft fault down to west is predicted in the Ugnu at 3,570-ft TVD. Hydrogen Sulfide · MPS Pad is not designated as an H2S Pad. Anti-collision Issues · MPS-27 must be minor risk based at 1 :200 to pass anti-collision issues. 5 ) ~ ~ )e Point MPS-32 Well Permit DRILL & COMPLETION PROCEDURE Pre-Rig Operations 1. Install 20-in insulated conductor. Procedure 1. MIRU. NU diverter on 20-in conductor and function test. 2. Drill 13-1/2" surface hole as per directional plan. 3. Case and cement 1 0-3/4" surface casing. 4. ND diverter, NU BOPE and test. 5. Perform FIT. 6. Drill 9-7/8" hole to land in top of the NB-sand as per directional plan. 7. Case and cement 7-5/8" intermediate casing. Freeze protect 7-5/8" x 10-3/4" annulus. 8. Drill out shoe and 20-ft new formation and perform FIT. 9. Drill 6-1/8" NB-sand lateral as per directional plan. 10. Run 5" uncemented sand screens and hang off 100-ft inside 7-5/8" casing. 11. Displace drilling mud to brine. 12. Run 4-1/2" jet pump completion as per schematic. 13. Land tubing hanger and test. 14. Set BPV. 15. ND BOP. 16. Install and test tree. 17. Pull BPV. 18. Test 7-5/8" x 4-1/2" annulus. 19. Freeze protect thru GLM. 20. Install BPV and secure well. 21. RD/MO. 6 TREE: Cameron 4-1/16" 5M WELLHEAD: FMC Gen 6 11 ", 5M Tubing Head: 11" x 4-1/2", FMC Tubing Hanger · "}i0iJOSl::lJ GOMpLI:: liON -~? ) KB. ELEV =72.0' Cellar Box ELEV = 38.1' 1121 20" 92 I bitt , H-40 Welded /~ Insulated Diesel Freeze protect to 500' M D 10-3/4" 45.5#, L-80, BTC-M Casing Drift: 9.875 Casing 10: 9.950 Coupling 00: 11.75" Burst: 5,210 psi Collapse: 2,480 psi ~ 9.7-lb/gat KGI with corrosion / inhibitor as packer fluid Jet Pump Installed in Sliding Sleeve Post rig! 7-5/8" 29.7#, L-80, BTC-M Casing Drift: 6.75 Casing ID: 6.875 Coupling 00: 11.75" Burst: 6,890 psi Collapse: 4,790 psi 7.625" Casing Shoe @ 7,557' MD; 3,937' TVD Well Inclination @ Shoe = 74 Degrees DATE REV. BY COMMENTS ... 42" Hole 4-1/2" x 1" Gas Lift Mandrel @ 2,200' MD; 1,965' TVO, 13-1/2" hole 4-1/2",12.6 Ibltt, L-80, IBT-M Coupling 00: 5.2" Orift/IO: 3.833" Burst: 8,430, 80% 6,744 psi Collapse: 7.500. 80%=6.000 psi .... 10-3/4"@ 3,105' MD, 2,382' TVDrkb "BIW 1- Wire Phoenix Pressure Gauge (3.850" 10, W/BIW 1- wire down to lower sensor) .-111 Phoenix Pressure Gauge (2.840" 10) - i~~ji ~ :?fD 7-5/8" x 4-1/2" Premier Packer ISet @ 7,400' MD 3-1/2" HES 'XN' nipple 2.750" 10 No Go W/RHC ball & rod Wireline Entry Guide 9-7/8" Hole ~ 5" Sand Screen Liner W/Baker HR-ZXP liner hanger -- -- - - - - - - - - -- NB Horizontal 6-1/8" hole 110,672' MD/3,882' TVD I Milne Point Unit WFI I : MPS-3? API NO: BP Exploration (Alaska) I I I r 1 1 h I I r I I f" --I I L I I I r I I ~ I I 4;) I ~ !-o.~-"; J l~ðQ, .._-T----T----T----T-J , ~ / . I .34 MPS-32t33 31 i .29i .27 .25 .24i ·23 .21i .20 .19i .18 11gi MPS-14j 13i MPS-12 11 .10 .9i .8 .7i ---·.6 ¡ ~ --- .2 .1 ) 33 21 I I ~ I I J I I I 1 I I ~ I I J .l StCT - - -1- ~ ~ ~~ ~12~. RIOt II T12tv. R~ . . I. I I ~ I - Z ..¿- I S 1E 29 2B PLANT ) 15·00'00" GRID- 35 31 \: K-"'~ '.~1 6 ~... 5 PR04JE~T3 S-~A~ì AREA 12 A 8 9 10 ,. 34 "'H-PAD T13N T12N 2 32 MPU S-PAD 11 Ww 13 ~:: 1B 0::0:: !,..EGEND -+- AS-BUILT CONDUCTOR . EXISTING CONDUCTOR 17 16 14 15 VICINITY MAP N.T.S. NOTES: 1. DATE OF SURVEY: JANUARY 15-16, 2003. 2. REFERENCE FIELD BOOK: MP03-01 PAGES 21-25. 3. COORDINATES ARE ALASKA STATE PLANE, ZONE-4 NAD-27. 4. GEODETIC COORDINATES ARE NAD-27. 5. MPU S-PAD AVERAGE SCALE FACTOR IS: 0.999904923. 6. HORIZONTAL CONTROL IS BASED ON MPU CFP MONUMENT CFP-3 AND MPU H-PAD MONUMENT H-1. 7. ELEVATIONS ARE BPX MEAN SEA LEVEL BASED ON MILNE POINT PIPELINE VERTICAL CONTROL. ~ 5i I ~ ~ J 2 ~ ID .. . !!l ¡ I f SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF JANUARY 16, 2003. LOCATED WITHIN PROTRACTED SEC. 12, T. 12 N., R. 10 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS MPS-12 Y=6,OOO,002.26 N= 2,237.04 70·24'37.604" 70.4104456· 38.7' 3,334' FSL X= 565,917.32 E= 6,793.91 149·27'47.701" 149.4632503· 93' FEL MPS-14 Y=5,999,994.47 N= 2,237.07 70·24'37.530" 70.4104250· 38.5' 3,327' FSL X= 565,888.13 E= 6,763.69 149·27'48.559" 149.4634886· 122' FEL MPS-32 Y=5,999,924.63 N= 2,237.08 70·24'36.866" 70.4102406· 38.1' 3,259' FSL X= 565,627.44 E= 6,493.78 149·27'56.218" 149.4656161· 383' FEL , ¡ i I ~ 0 1 /17 /O~ 1SS\JfD Fœ Hf'ORIA liON i NO. DA1E RE\1S1ON FROb' DRAWN: Obp JACOBS l~-- CHECKED: DROEGE ~ 0 , DAlE: 1/17/03 II" . DRAWING: MILNE POINT UNIT S-P AD SHEET: ....J.-_-.J_ FRB03 MPS 04-00 ~ ffi~rnœo JOe NO: AS-BUlL T CONDUCTORS SCALE: JJ RfA GICIfCIIItI ,., \MD MW:'IQItI WELLS MPS-12, MPS-14 & MPS-32 1 OF 1 ... IØI ......... INC 1·· 160' BY CHI( _ IUa<A ....., Plan: MPS-32 W~J7 (plan MPS-32ilPlan MPS-32i Crf31ed By: Ken Allen Dale: 4/2212003 Checked: Dale: Reviewed: Dale: SURVEY PROGRAM Depth Fm Depth To S"""y/P1an Tool 33.00 850.00 Planned: MPS-32 W¡1J7 VI CB.GYRO-SS 850.00 10672.12 PIanœd: MPS-32 Wp01 VI MWD<-IFR+MS REFERENCE INFORMATION Co-<>ldioaœ (N/E) Reference: Well Centre: Plan MPS-32i. True NO<1h Vertical (fVDJ Reference: S-Pad Dev 12.00 Section (VS) Reference: Slot· (O.ooN,O.OOE) Measured Depth Reference: S-Pad Dev 12.00 Calculatioo Me1hod: Minimum ûuvalure COMPANY DHAILS RP Amoco Calculation Mclbod: Minimum Curvature llc~r ~¡= ~~;~OOer North Error Surface: Elliptical + Casing Wamiu~ Method: Rules ßascd ö WELL DETAll.S Name +NI.s +EJ-W Northing Easting Latitude Longitude SI, Plan MPS-32i -41.02 ·111.84 5999924.61 5656rJ.bI 10"24'36.866N 149"21'56211W NlA TARGET DETAll.S Narœ lVD +NI-S +FJ-W Northing Easting Shape Faultf:l 3592.00 2628.02 -4û15.l2 60025 11.00 61590.00 PolygolI MPS-08 T5 3882.00 312.44 ·1051.87 6000115.00 58568.00 Point MPS-08 T4 3912.00 116250 -636931 6001031.00 59249.00 Point MPS-08T3 39rJ.00 1693.49 -590458 6001566.00 59109.00 Point MPS-08 Tl 3931.00 2564.05 -4930.80 6002445.00 60615.00 Point MPS-08 Poly 3931.00 rJrJ.9fJ -502431 6002608.00 60580.00 PolygolI .~ Targe MPS-08 Tl MPS-08 T3 VSec 0.00 0.00 0.18 1.91 256.16 451.47 548.20 1030.57 3822.38 5039.37 5224.72 5343.89 5450.46 5973.70 6042.59 6384.62 6414.49 7064.78 TFace 0.00 0.00 345.00 323.60 349.15 0.00 0.00 -15.67 0.00 -95.89 -32.16 0.00 -140.78 0.00 -72.07 0.00 -82.28 0.00 DLeg 0.00 0.00 1.50 2.50 3.00 2.00 0.00 4.00 0.00 4.00 12.00 0.00 6.00 0.00 4.00 0.00 4.00 0.00 SECTION DETAILS +N/-S +FJ-W 0.00 0.00 -0.15 -1.78 -246.89 -435.39 -528.76 -996.85 -3715.64 -4930.80 -5121.67 -5245.44 -5356.57 -5904.58 -5976.98 -6337.74 -6369.31 -7057.87 0.00 0.00 0.56 2.99 214.96 373.13 451.47 784.64 2495.74 2564.05 2443.49 2342.15 2241.50 1693.49 1615.80 1200.15 1162.50 312.44 TVD 33.00 300.00 366.66 452.04 1421.69 1736.64 1872.00 2264.78 3471.94 3937.00 3955.88 3936.20 3927.00 3927.00 3925.79 3913.23 3912.00 3882.00 Azi 0.00 0.00 345.00 320.00 310.00 310.00 310.00 302.18 302.18 245.00 230.69 230.69 225.00 225.00 220.96 220.96 219.01 219.01 Inc 0.00 0.00 1.00 3.00 34.00 42.00 42.00 69.40 69.40 73.50 97.01 97.01 90.00 90.00 91.31 91.31 91.57 91.57 MD 33.00 300.00 366.67 452.10 1487.08 1887.08 2069.23 2772.24 6204.00 7556.60 7785.32 7946.50 8096.87 8871.87 8978.10 9528.62 9577.76 10672.12 Sec 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 All TVD depths are ssTVD plus 72'lor RKBE. ,~ I I ~ I", , ",ø>, , , # ~ Start Dir 1.5/100' : 300' MD, 300TVD Start Dir 2.5/100' : 366.67' MD, 366.66'1VD Start Dir 3/100' : 452.1' MD. 452.04'TYD A- 800 MPS-08 T4 MPS-08 T5 FORMATION TOP DETAILS No. TVDPath MDPath Formation 1 1822.00 2001.95 BPRF 2 3542.00 6400.12 TUZC 3 3713.00 6871.50 TUZB 4 3915.00 7480.72 SBF2-NA 5 3932.00 7539.08 NAMF 6 3937.00 7556.60 SBFI-NB 7 3944.00 7583.41 SBFI-NBR CASING DETAILS No. TVD MD Name Size 1 2382.00 3105.47 103/4" ~ ?6i~0 .~ 2 3937.00 7556.60 75/8" 3 3882.02 10672.11 5" screens 5.000 7556.6' MD, 3937'1VD 7785.32' MD, 3955.88' TYD Start Dir 6/100' : 7946.5' MD, 3936.2'1VD I End Dir : 8096.87' MD, 3927' TYD I. S.tart Dir 4/100' : 8871..87' MD, 3927'TVD I End Dir : 8978.1' MD, 3925.79' TYD § I I, ..' .. MPS-32 Wp07 <. '.. J... ... _ .. .~... . . J I -0 T "'10[11) ,. 1'" '"I" 5~ h~ fl.[), WI \ !1'1 v[, r J D,~ iJ~77 7¡, MD, ~lJl:>'TV[J . I T..L"I [' j,,¡,7:> I:' I\' : I )CJUU <MUU 7200 121100' Start Dir 4800 6204' MD, 3471.94'1VD Start Dir 4/100' ruzs I 4000 [800ft/in] 3200 Vertical Section at 272.53 1487.08' MD, 1421.69'1VD 1887.08' MD, 1736.64'TYD 2069.23' MD, 1872TVD 2772.24' MD, 2264.78' TYD ~ 800 1600 2400 ~ 1600 ¢: o ~ .c i5. Q ] .~ > ~ 2400 3200 4000 Plan: MPS-32 Wp)7 (plan MPS-32ilPlan MPS-321 Cræ1ed By: Ken Allen Date: 4/22/2003 Checked: Date: Date: SURVEY PROGRAM Depth Fm Depth To s.m·eyiPlan Tool .00 850.00 Planned: MPS-32 WplJI VI CB-GYRO-SS 0.00 10672.12 P1anned: MPS-32 WplJI VI MWD+1FR+MS REFERENCE INFORMATION Well Centre: Plan MPS-32~ True North S-Pad Dev 72.00 Slot- (O.ooN,O.ooE) S-Pad Dev 72.00 Minimum Curvature Co-ordinaIe (N/E) Reference: VerticaJ (I,ID) Reference: Section (VS) Reference: Measured Depth Reference: Cakulalion Method; COMPANY DETAIlS P Amoco Minimum Curvature ISCWSA Trav Cylioo,r North Elliptical + Casing Rulos B.=d ö WELL DETAILS Name +W-S +Ð-W Northing Easting Latitude Longitude Slot Plan MPS·32i -47.02 ·717.84 5999924.61 565621.61 70"24'36866N 149"27'56211W WA TARGET DETAIlS Name TVD +NI·S +Ð·W Northing Easting Shape Fault#l 3592.00 2628.02 -4015.12 6002517.00 61590.00 Polygon MPS-œ 15 3882.00 312.44 -7057.87 6000175.00 58568.00 Point MPS.j)8 T4 3912.00 116250 .{iJ693 I 6001031.00 59249.00 Point MPS.j)8 13 3927.00 1693.49 -590458 6001566.00 59709.00 Point MPS.j)8 TI 3937.00 2564.05 -4930.80 6002445.00 60675.00 Point MPS-08 Poly 3937.00 2727.91] -502437 6002608.00 60580.00 Polygon All TVD depths are ssTVD plus 72'for RKBE. Calculation ~Icthod; Error Syslem: Scao Method: Error Surfåcc: Wami"R Method: -~ Target MPS-08 T1 VSee 0.00 0.00 0.18 1.91 256.16 451.47 548.20 1030.57 3822.38 5039.37 5224.72 5343.89 5450.46 5973.70 6042.59 6384.62 6414.49 7064.78 SECTION DETAILS See MD Ine Azi TVD +N/-S +EJ-W DLeg TFaee 1 33.00 0.00 0.00 33.00 0.00 0.00 0.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 3 366.67 1.00 345.00 366.66 0.56 -0.15 1.50 345.00 4 452.10 3.00 320.00 452.04 2.99 -1.78 2.50 323.60 5 1487.08 34.00 310.00 1421.69 214.96 -246.89 3.00 349.15 6 1887.08 42.00 310.00 1736.64 373.13 -435.39 2.00 0.00 7 2069.23 42.00 310.00 1872.00 451.47 -528.76 0.00 0.00 8 2772.24 69.40 302.18 2264.78 784.64 -996.85 4.00 -15.67 9 6204.00 69.40 302.18 3471.94 2495.74 -3715.64 0.00 0.00 10 7556.60 73.50 245.00 3937.00 2564.05 -4930.80 4.00 -95.89 11 7785.32 97.01 230.69 3955.88 2443.49 -5121.67 12.00 -32.16 12 7946.50 97.01 230.69 3936.20 2342.15 -5245.44 0.00 0.00 13 8096.87 90.00 225.00 3927.00 2241.50 -5356.57 6.00 -140.78 14 8871.87 90.00 225.00 3927.00 1693.49 -5904.58 0.00 0.00 15 8978.10 91.31 220.96 3925.79 1615.80 -5976.98 4.00 -72.07 16 9528.62 91.31 220.96 3913.23 1200.15 -6337.74 0.00 0.00 17 9577. 76 91.57 219.01 3912.00 1162.50 -6369.31 4.00 -82.28 18 10672.12 91.57 219.01 3882.00 312.44 -7057.87 0.00 0.00 ~ ~ ~ ~ 01' /<:òO ~ ,riP ,I ,I ¡P 1,#, , # #, , # # ;-. 3200-- MPS-08 T3 MPS-08 T4 MPS-08 T5 Formation BPRF TUZC TUZB SBF2-NA NAMF SBFI-NB SBFI-NBR .---~ ~ ",-- 0 10.750 7.625 5.000 Size FORMATION TOP DETAILS TVDPath MDPath CASING DETAILS 103/4" 7 5/8" 5" screens 2001.95 6400.12 6871.50 7480.72 7539.08 7556.60 7583.41 Name --,. ,--' -~ - 1Pl _ ~J'~~ ~~~ =r~c 1r2/~-º-º, ŒLl1£u,'n ! - stat 451.1? M'[( .¡: - - - - .. ;~~~Sfartbg_~~}~(tri 5~~1L t\fD. T---) ---- <;:~>Tn)fr )! 'itl 00' , "JI)' I I I I -1600 3105.47 7556.60 10672.11 1822.00 3542.00 3713.00 3915.00 3932.00 3937.00 3944.00 -800 MD TVD 2382.00 3937.00 3882.02 No. 487. I 1 2 3 4 5 6 7 ~nt- _n~ nn;ntnnt/ 01 ~Tr\.~ "8 m : No. 1 2 3 I 3471.94'TVD .....,-.. "'<..:..~- '........ , '3000 -......J : : : "'h. · ::--.....,........ - . '........ . '" · : "'- : "- : " : ,L: ULJ ~ . · : .- , .-- I West(-)/East(+) [800ft/in] I 6204' MD, Start Dir 4/1 00' ..---. I I MPs·IIX T '''''~ 7 ~Jx' " ... -~ , \ -- - ,." ...' --\, , "" ' """ " " ' End )rr . '\. ," SL..ln " End ri,l : - . ~x71 87' MD.. 3l~7TVD . MD. ~lJ~\N' TVD - - - . , , , , : : - I l--r-r I, -4800 ~ 3'TVD I -5600 I ·6400 I -7200 2400 600 800 c ~ o o ~ +' :E 1:: o ~ :; o en ) BP KW A Planning Report MAP ') . C()mpa~y: . BPAmoco Field: . Milne Point S~te:;; M PtSIRaq 'YeÜ( ." Pla~ MpS~ª2i Wehpath:" plarl MPS-32i Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level ; Date: 4/22/2003 Time: '/16:19:03 .' Page: Cö~ordi~a!e(NF;.) R~re..enc,e:>; Well:: plan MPS-32i) True North V~t;tlcaI{TND)..Ref~reÏ1ce;<' .$rP~dibev 72.0 ....... . .... St(c~ion; (V.~) ~~(er~~c~:W~Jr (O.OON. 0~00E;?72.53Azi} SurveyC~lcula~ionM~th~.d:·/ 'Minimum curVature' Db: Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 Site: M pt S Pad Site Position: From: Map Position Uncertainty: Ground Level: Northing: Easting: 5999978.00 ft 566345.00 ft Latitude: Longitude: North Reference: Grid Convergence: 70 24 37.329 N 149 27 35.171 W True 0.51 deg 0.00 ft 0.00 ft Well: Plan MPS-32i Slot Name: Well Position: +N/~S ~47.02 ft Northing: 5999924.61 ft +E/-W -717.84 ft Easting: 565627.67 ft Position Uncertainty: 0.00 ft Latitude: Longitude: 70 24 36.866 N 149 27 56.211 W Wellpath: Plan MPS-32i Plan: MPS-32 Wp07 Date Composed: Version: Tied-to: Well Ref.· Point 0.00 ft Mean Sea Level 26.21 deg 80.79 deg Direction deg 272.53 3/6/2003 13 From: Definitive Path +N/~S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/~W ft 0.00 Current Datum: Magnetic Data: Field Strength: Vertical Section: S-Pad Dev 6/29/2001 57481 nT Depth From (TV D) ft 0.00 Height 72.00 ft Principal: Yes Casing Points MD TVD Diameter Hole Size Nam~: ft ft in in 3105.47 2382.00 10.750 13.500 10 3/4" 7556.60 3937.00 7.625 9.875 75/8" 1 0672.11 3882.02 5.000 6.125 5" screens Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 2001.95 1822.00 BPRF 0.00 0.00 6400.12 3542.00 TUZC 0.00 0.00 6871.50 3713.00 TUZB 0.00 0.00 7480.72 3915.00 SBF2-NA 0.00 0.00 7539.08 3932.00 NAMF 0.00 0.00 7556.60 3937.00 SBF1-NB 0.00 0.00 7583.41 3944.00 SBF1-NBR 0.00 0.00 0.00 SBE4-NC 0.00 0.00 Targets Map Map <-- Latitude -> <- Longitude -> Name Description TVD +N/-S +EI-W Northing Easting Deg Min Sec Deg Mln Sec Dip. Dlr. ft ft ft ft ft Fault#1 3592.00 2628.02 -4015.12 6002517.00 561590.00 70 25 2.701 N 149 29 53.937 W -Polygon 1 3592.00 2628.02 -4015.12 6002517.00 561590.00 70 25 2.701 N 149 29 53.937 W -Polygon 2 3592.00 2661.11 -4138.85 6002549.00 561466.00 70 25 3.026 N 149 29 57.566 W MPS-08 T5 3882.00 312.44 -7057.87 6000175.00 558568.00 70 24 39.906 N 149 31 23.089 W MPS-08 T4 3912.00 1162.50 -6369.31 6001031.00 559249.00 70 24 48.272 N 149 31 2.927 W ) BP KW A Planning Report MAP ) Compàny: BPAmoco Field: MilhePoint Site:.; MJ:>fs påd w~n:,.., Plån' MP$~32i Wëllpath: Pláh MP~~32i Targets Date:' :4/22/2003 Time:~ 16:19,:,03, . .' . ..... ...Påg~: , qO;9~~Jnate(NE);~~ferel1.ce: ,^,ell:;PI~,n MPS-32i;, J;ryf3,~Nprth> ' ~;~r;t~ç~1 (T~)I\~~eren~~:., S,.Pad DEW 72.0<",/\ ..,: '.. .',: S;~c~i~~: (VS);.~~f~~ence::: .~ WeIÜO.9þ~,O.00E,~~g;~~A;i) ..::';. . .~.; S*rvëy:Calc~latíôn: Met~od: Minitnurit Curvaturf3:'/<;'Pb::': Orééle ~:;Name" ':)j~~criPJhm'.. . :D~p~ Dir ~ ~'jf : Map L()ngitude .:. +N/-$ +Ef-W NØ~~hing Eastiþg: M:in See: ·.':f(:: ft {Jt:;,' . ff 3927.00 1693.49 -5904.58 6001566.00 559709.00 70 24 53.498 N 149 30 49.316 W 3937.00 2564.05 -4930.80 6002445.00 560675.00 70 25 2.067 N 149 30 20.785 W 3937.00 2727.90 -5024.37 6002608.00 560580.00 70 25 3.678 N 149 30 23.532 W 3937.00 2727.90 -5024.38 6002608.00 560579.99 70 25 3.678 N 149 30 23.532 W 3937.00 2400.38 -4857.23 6002281.99 560750.00 70 25 0.458 N 149 30 18.625 W 3937.00 1652.11 -5747.92 6001526.00 559866.00 70 24 53.092 N 149 30 44.723 W 3937.00 131 .46 -6948.44 5999995.00 558679.00 70 24 38.127 N 149 31 19.877 W 3937.00 418.37 -7161.95 6000280.00 558463.00 70 24 40.947 N 149 31 26.143 W 3937.00 1811.27 -5991.55 6001682.99 559621.00 70 24 54.656 N 149 30 51.869 W MPS-08 T3 MPS-08 T1 MPS-08 Poly -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 Plan Section Information MD InCl Azim 'TV]) +N/-S +E/-W: > DLSBuild Turn <, TFO' Target>: ft deg d~g ft, ft ft ',deg/100ft deg/tOOft deg/100ft deg 33.00 0.00 0.00 33.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 366.67 1.00 345.00 366.66 0.56 -0.15 1.50 1.50 0.00 345.00 452.10 3.00 320.00 452.04 2.99 -1.78 2.50 2.34 -29.26 323.60 1487.08 34.00 310.00 1421.69 214.96 -246.89 3.00 3.00 -0.97 349.15 1887.08 42.00 310.00 1736.64 373.13 -435.39 2.00 2.00 0.00 0.00 2069.23 42.00 310.00 1872.00 451.47 -528.76 0.00 0.00 0.00 0.00 2772.24 69.40 302.18 2264.78 784.64 -996.85 4.00 3.90 -1.11 -15.67 6204.00 69.40 302.18 3471.94 2495.74 -3715.64 0.00 0.00 0.00 0.00 7556.60 73.50 245.00 3937.00 2564.05 -4930.80 4.00 0.30 -4.23 -95.89 MPS-08 T1 7785.32 97.01 230.69 3955.88 2443.49 -5121.67 12.00 10.28 -6.26 -32.16 7946.50 97.01 230.69 3936.20 2342.15 -5245.44 0.00 0.00 0.00 0.00 8096.87 90.00 225.00 3927.00 2241.50 -5356.57 6.00 -4.66 -3.78 -140.78 8871.87 90.00 225.00 3927.00 1693.49 -5904.58 0.00 0.00 0.00 0.00 MPS-08 T3 8978.10 91.31 220.96 3925.79 1615.80 -5976.98 4.00 1.23 -3.81 -72.07 9528.62 91.31 220.96 3913.23 1200.15 -6337.74 0.00 0.00 0.00 0.00 9577.76 91.57 219.01 3912.00 1162.50 -6369.31 4.00 0.54 -3.97 -82.28 MPS-08 T4 10672.12 91.57 219.01 3882.00 312.44 -7057.87 0.00 0.00 0.00 0.00 MPS-08 T5 Survey MD Incl Azim TVD Sys TVD MapN MapE VS DLS TFO Tool/Comment ft deg deg ft ft ft ft ft deg/100ft deg 33.00 0.00 0.00 33.00 -39.00 5999924.61 565627.67 0.00 0.00 0.00 CB-GYRO-SS 100.00 0.00 0.00 100.00 28.00 5999924.61 565627.67 0.00 0.00 0.00 CB-GYRO-SS 200.00 0.00 0.00 200.00 128.00 5999924.61 565627.67 0.00 0.00 0.00 CB-GYRO-SS 300.00 0.00 0.00 300.00 228.00 5999924.61 565627.67 0.00 0.00 0.00 CB-GYRO-SS 366.67 1.00 345.00 366.66 294.66 5999925.17 565627.51 0.18 1.50 0.00 CB-GYRO-SS 400.00 1.74 328.51 399.99 327.99 5999925.88 565627.17 0.55 2.50 323.60 CB-GYRO-SS 452.10 3.00 320.00 452.04 380.04 5999927.59 565625.86 1.91 2.50 340.08 CB-GYRO-SS 500.00 4.42 316.49 499.84 427.84 5999929.87 565623.77 4.09 3.00 349.15 CB-GYRO-SS 600.00 7.40 313.51 599.30 527.30 5999937.04 565616.38 11.73 3.00 352.65 CB-GYRO-SS 700.00 10.40 312.24 698.08 626.08 5999947.44 565604.93 23.54 3.00 355.62 CB-GYRO-SS 800.00 13.40 311.53 795.92 723.92 5999961.05 565589.45 39.49 3.00 356.87 CB-GYRO-SS 900.00 16.39 311.08 892.55 820.55 5999977.84 565570.00 59.53 3.00 357.56 MWD+IFR+MS 1000.00 19.39 310.77 987.70 915.70 5999997.75 565546.61 83.61 3.00 358.00 MWD+IFR+MS 1100.00 22.39 310.53 1 081. 12 1009.12 6000020.73 565519.35 111.67 3.00 358.30 MWD+IFR+MS 1200.00 25.39 310.35 1172.54 1100.54 6000046.72 565488.31 143.62 3.00 358.52 MWD+IFR+MS 1300.00 28.39 310.21 1261.72 1189.72 6000075.65 565453.55 179.38 3.00 358.68 MWD+IFR+MS 1400.00 31.39 310.09 1348.41 1276.41 6000107.44 565415.19 218.85 3.00 358.81 MWD+IFR+MS 1487.08 34.00 310.00 1421.69 1349.69 6000137.37 565378.92 256.16 3.00 358.92 MWD+IFR+MS 1500.00 34.26 310.00 1432.38 1360.38 6000141.98 565373.33 261.91 2.00 0.00 MWD+IFR+MS -'.--. ---"'-"--.-' - .,..--,-,--.,-"---~-----,.,,. -- --..----.-.-.-- _._,----",,- --,------ _.. ,_~___.._,__"'"_.__....._.____ ___._ _._..__.u_ _ _____ '.__....________.___.,. - ,- ,,--.--. - ---,------ - -- '.-- ----.-.-..-.-. -----,-...-.--, --'-,.'-'-----,----" ) ) BP KW A Planning Report MAP Comp~IÍY1 BPAniOco Date:"A/2:2/2003, Tillie: " 16:19:03 ' ·page: F~el~: ."'> : Milne ~9lnt CQ-:Ql'di,~at~O~E)~er~ren~e: tj,,' ',Well: Plan MPS-32i,TrueNorth Si.te;.:, ' M. Pt S::pad ' Yert~cal(TYP) I}:~.rerence: ': \;' ^S,:padD~v 7~.(j '" . , 'V:eIJ;. '.,. Plan MPS-32i ~e~tlp~,(V~)l}:ef~~~n~~: '.':, '" ;:; 'WEIll (O.OºN,Q.OOE,2?2.5~~I) , Wellþåth: PI~m MPS-32i Survè~;Çalc.ulati~n Method:": . . Ntihlmum;Çul'yature ' " "'Db: Survey 'MD, Incli Aiilli TVD Sys TVD MapN VS~ ' FDLS TFO Tool/Comment ;;; ft" :: deg dëg ft i ft'· ' :"'fti, ft:- . ;qeg/10Qn :~~g. 1600.00 36.26 310.00 1514.03 1442.03 6000178.69 565328.79 307.73 2.00 0.00 MWD+IFR+MS 1700.00 38.26 310.00 1593.62 1521.62 6000217.19 565282.08 355.78 2.00 0.00 MWD+IFR+MS 1800.00 40.26 310.00 1671.05 1599.05 6000257.44 565233.25 406.00 2.00 0.00 MWD+IFR+MS 1887.08 42.00 310.00 1736.64 1664.64 6000293.86 565189.06 451.4 7 2.00 0.00 MWD+IFR+MS 1900.00 42.00 310.00 1746.24 1674.24 6000299.36 565182.39 458.33 0.00 0.00 MWD+IFR+MS 2000.00 42.00 310.00 1820.55 1748.55 6000341.92 565130.76 511.44 0.00 0.00 MWD+IFR+MS 2001.95 42.00 310.00 1822.00 1750.00 6000342.75 565129.76 512.47 0.00 0.00 BPRF 2069.23 42.00 310.00 1872.00 1800.00 6000371.38 565095.02 548.20 0.00 0.00 MWD+IFR+MS 2100.00 43.19 309.51 1894.65 1822.65 6000384.55 565078.89 564.79 4.00 344.33 MWD+IFR+MS 2200.00 47.05 308.07 1965.20 1893.20 6000428.42 565023.28 621.93 4.00 344.69 MWD+IFR+MS 2300.00 50.94 306.80 2030.80 1958.80 6000473.73 564962.96 683.82 4.00 345.71 MWD+IFR+MS 2400.00 54.83 305.66 2091.14 2019.14 6000520.27 564898.24 750.16 4.00 346.54 MWD+IFR+MS 2500.00 58.74 304.63 2145.90 2073.90 6000567.80 564829.42 820.63 4.00 347.23 MWD+IFR+MS 2600.00 62.65 303.68 2194.84 2122.84 6000616.09 564756.84 894.88 4.00 347.80 MWD+IFR+MS 2700.00 66.57 302.79 2237.71 2165.71 6000664.92 564680.86 972.55 4.00 348.26 MWD+IFR+MS 2772.24 69.40 302.18 2264.78 2192.78 6000700.38 564624.06 1030.57 4.00 348.64 MWD+IFR+MS 2800.00 69.40 302.18 2274.55 2202.55 6000714.03 564601.95 1053.15 0.00 0.00 MWD+IFR+MS 2900.00 69.40 302.18 2309.72 2237.72 6000763.19 564522.30 1134.50 0.00 0.00 MWD+IFR+MS 3000.00 69.40 302.18 2344.90 2272.90 6000812.35 564442.65 1215.86 0.00 0.00 MWD+IFR+MS 3100.00 69.40 302.18 2380.08 2308.08 6000861.50 564363.00 1297.21 0.00 0.00 MWD+IFR+MS 3200.00 69.40 302.18 2415.25 2343.25 6000910.66 564283.35 1378.56 0.00 0.00 MWD+IFR+MS 3300.00 69.40 302.18 2450.43 2378.43 6000959.82 564203.69 1459.91 0.00 0.00 MWD+IFR+MS 3400.00 69.40 302.18 2485.60 2413.60 6001008.98 564124.04 1541.27 0.00 0.00 MWD+IFR+MS 3500.00 69.40 302.18 2520.78 2448.78 6001058.14 564044.39 1622.62 0.00 0.00 MWD+IFR+MS 3600.00 69.40 302.18 2555.96 2483.96 6001107.29 563964.74 1703.97 0.00 0.00 MWD+IFR+MS 3700.00 69.40 302.18 2591.13 2519.13 6001156.45 563885.09 1785.32 0.00 0.00 MWD+IFR+MS 3800.00 69.40 302.18 2626.31 2554.31 6001205.61 563805.43 1866.67 0.00 0.00 MWD+IFR+MS 3900.00 69.40 302.18 2661.48 2589.48 6001254.77 563725.78 1948.03 0.00 0.00 MWD+IFR+MS 4000.00 69.40 302.18 2696.66 2624.66 6001303.93 563646.13 2029.38 0.00 0.00 MWD+IFR+MS 4100.00 69.40 302.18 2731.84 2659.84 6001353.08 563566.48 2110.73 0.00 0.00 MWD+IFR+MS 4200.00 69.40 302.18 2767.01 2695.01 6001402.24 563486.82 2192.08 0.00 0.00 MWD+IFR+MS 4300.00 69.40 302.18 2802.19 2730.19 6001451.40 563407.17 2273.44 0.00 0.00 MWD+IFR+MS 4400.00 69.40 302.18 2837.36 2765.36 6001500.56 563327.52 2354.79 0.00 0.00 MWD+IFR+MS 4500.00 69.40 302.18 2872.54 2800.54 6001549.72 563247.87 2436.14 0.00 0.00 MWD+IFR+MS 4600.00 69.40 302.18 2907.72 2835.72 6001598.87 563168.22 2517.49 0.00 0.00 MWD+IFR+MS 4700.00 69.40 302.18 2942.89 2870.89 6001648.03 563088.56 2598.84 0.00 0.00 MWD+IFR+MS 4800.00 69.40 302.18 2978.07 2906.07 6001697.19 563008.91 2680.20 0.00 0.00 MWD+IFR+MS 4900.00 69.40 302.18 3013.25 2941.25 6001746.35 562929.26 2761.55 0.00 0.00 MWD+IFR+MS 5000.00 69.40 302.18 3048.42 2976.42 6001795.51 562849.61 2842.90 0.00 0.00 MWD+IFR+MS 5100.00 69.40 302.18 3083.60 3011.60 6001844.66 562769.96 2924.25 0.00 0.00 MWD+IFR+MS 5200.00 69.40 302.18 3118.77 3046.77 6001893.82 562690.30 3005.61 0.00 0.00 MWD+IFR+MS 5300.00 69.40 302.18 3153.95 3081.95 6001942.98 562610.65 3086.96 0.00 0.00 MWD+IFR+MS 5400.00 69.40 302.18 3189.13 3117.13 6001992.14 562531.00 3168.31 0.00 0.00 MWD+IFR+MS 5500.00 69.40 302.18 3224.30 3152.30 6002041.30 562451.35 3249.66 0.00 0.00 MWD+IFR+MS 5600.00 69.40 302.18 3259.48 3187.48 6002090.46 562371.70 3331.01 0.00 0.00 MWD+IFR+MS 5700.00 69.40 302.18 3294.65 3222.65 6002139.61 562292.04 3412.37 0.00 0.00 MWD+IFR+MS 5800.00 69.40 302.18 3329.83 3257.83 6002188.77 562212.39 3493.72 0.00 0.00 MWD+IFR+MS 5900.00 69.40 302.18 3365.01 3293.01 6002237.93 562132.74 3575.07 0.00 0.00 MWD+IFR+MS 6000.00 69.40 302.18 3400.18 3328.18 6002287.09 562053.09 3656.42 0.00 0.00 MWD+IFR+MS 6100.00 69.40 302.18 3435.36 3363.36 6002336.25 561973.43 3737.77 0.00 0.00 MWD+IFR+MS 6204.00 69.40 302.18 3471.94 3399.94 6002387.37 561890.60 3822.38 0.00 0.00 MWD+IFR+MS 6300.00 69.06 298.09 3505.99 3433.99 6002431.74 561812.61 3901.90 4.00 264.11 MWD+IFR+MS ) '. BP ) KW A Planning Report MAP .' '<Z0mpany: BPAmöco' . J)at~: . 4/22/~003< Tinít~i,~:16:19:03>' '." ,,·.P~ge: ,',;Eield:; MiJ!1!3 point;) : {Co-()rdinate(~f)Re~et:ence:iMl~II: ~Ian MPS-~21, True'North .,.:Site: .....; MPt S¡Pad\:: 'v: ertlcal ('IND), ~efe~ence: $.-Pad(Devi7?·O.>· .... ..... ..... y:», ell:' . Plan M.þS~~2( . Se~tion; (~~) ~,efu~.lÎce: Well (º.00N:;º.00E;2?~.53~lr. ·'.~ellp..th: Plan rv!P$"32i· : Su¡'veyCalcu~åti9nn\'Iethod: Minlmùm.CÜïvatÙre'< ":Db: . .. .. . ~. Survey ¿.MD·" '. Ir(ël ; . Ázlin TVD' · SysTVD;,t' M~þN' /MapE vs/;" DLS ,,<':TFO; Tool/Comment: 'i:\,;'ft geg g'~g ;tt\ >Jt <;ft:: ;:ft+ ;hi,;: deg!100ft deg ~;. <,~y 6400.00 68.80 293.82 3541.96 3469.96 6002471.83 561728.38 3987.50 4.00 265.56 MWD+IFR+MS 6400.12 68.80 293.82 3542.00 3470.00 6002471.88 561728.28 3987.61 0.00 0.00 TUZe 6500.00 68.66 289.53 3578.25 3506.25 6002505.47 561641.52 4075.51 4.00 267.10 MWD+IFR+MS 6537.75 68.63 287.91 3592.00 3520.00 6002516.46 561608.12 4109.28 4.00 268.66 Fault#1 6600.00 68.62 285.23 3614.69 3542.69 6002532.50 561552.43 4165.51 4.00 269.25 MWD+IFR+MS 6700.00 68.69 280.94 3651.11 3579.11 6002552.77 561461.57 4257.05 4.00 270.22 MWD+IFR+MS 6800.00 68.87 276.65 3687.33 3615.33 6002566.21 561369.36 4349.68 4.00 271.79 MWD+IFR+MS 6871.50 69.06 273.59 3713.00 3641.00 6002571.58 561302.86 4416.34 4.00 273.34 TUZB 6900.00 69.15 272.38 3723.16 3651.16 6002572.73 561276.26 4442.96 4.00 274.44 MWD+IFR+MS 7000.00 69.54 268.12 3758.45 3686.45 6002572.31 561182.72 4536.43 4.00 274.87 MWD+IFR+MS 7100.00 70.04 263.89 3793.00 3721.00 6002564.96 561089.20 4629.64 4.00 276.37 MWD+IFR+MS 7200.00 70.63 259.69 3826.67 3754.67 6002550.69 560996.16 4722.13 4.00 277.84 MWD+IFR+MS 7300.00 71.32 255.52 3859.27 3787.27 6002529.60 560904.04 4813.46 4.00 279.25 MWD+IFR+MS 7400.00 72.11 251.39 3890.66 3818.66 6002501.77 560813.29 4903.17 4.00 280.61 MWD+IFR+MS 7480.72 72.80 248.09 3915.00 3843.00 6002474.49 560741.34 4974.11 4.00 281.91 SBF2-NA 7500.00 72.97 247.30 3920.67 3848.67 6002467.34 560724.36 4990.83 4.00 282.90 MWD+IFR+MS 7539.08 73.33 245.71 3932.00 3860.00 6002452.13 560690.20 5024.44 4.00 283.13 NAMF 7556.60 73.50 245.00 3937.00 3865.00 6002445.00 560675.00 5039.37 4.00 283.59 MPS-08 Poly 7575.00 75.37 243.79 3941.94 3869.94 6002437.20 560659.09 5055.00 12.00 327.84 MWD+IFR+MS 7583.41 76.23 243.24 3944.00 3872.00 6002433.50 560651.82 5062.13 12.00 328.17 SBF1-NBR 7600.00 77.93 242.17 3947.71 3875.71 6002425.96 560637.52 5076.16 12.00 328.30 MWD+IFR+MS 7625.00 80.49 240.58 3952.39 3880.39 6002414.00 560616.07 5097.17 12.00 328.54 MWD+IFR+MS 7650.00 83.06 239.02 3955.97 3883.97 6002401.37 560594.80 5117.98 12.00 328.84 MWD+IFR+MS 7675.00 85.64 237.47 3958.43 3886.43 6002388.10 560573.77 5138.53 12.00 329.06 MWD+IFR+MS 7700.00 88.21 235.94 3959.77 3887.77 6002374.21 560553.03 5158.77 12.00 329.22 MWD+IFR+MS 7725.00 90.79 234.41 3959.99 3887.99 6002359.76 560532.64 5178.63 12.00 329.30 MWD+IFR+MS 7750.00 93.37 232.87 3959.08 3887.08 6002344.77 560512.66 5198.08 12.00 329.31 MWD+IFR+MS 7775.00 95.95 231.33 3957.04 3885.04 6002329.30 560493.13 5217.04 12.00 329.26 MWD+IFR+MS 7785.32 97.01 230.69 3955.88 3883.88 6002322.77 560485.22 5224.72 12.00 329.13 MWD+IFR+MS 7800.00 97.01 230.69 3954.09 3882.09 6002313.45 560474.03 5235.57 0.00 0.00 MWD+IFR+MS 7900.00 97.01 230.69 3941.88 3869.88 6002249.90 560397.80 5309.51 0.00 0.00 MWD+IFR+MS 7946.50 97.01 230.69 3936.20 3864.20 6002220.36 560362.35 5343.89 0.00 0.00 MWD+IFR+MS 7950.00 96.85 230.56 3935.78 3863.78 6002218.13 560359.69 5346.48 6.00 219.22 MWD+IFR+MS 8000.00 94.52 228.65 3930.82 3858.82 6002185.56 560322.09 5382.90 6.00 219.20 MWD+IFR+MS 8050.00 92.19 226.77 3927.90 3855.90 6002151.66 560285.47 5418.30 6.00 219.01 MWD+IFR+MS 8096.87 90.00 225.00 3927.00 3855.00 6002118.75 560252.12 5450.46 6.00 218.90 MWD+IFR+MS 8100.00 90.00 225.00 3927.00 3855.00 6002116.51 560249.93 5452.57 0.00 0.00 MWD+IFR+MS 8200.00 90.00 225.00 3927.00 3855.00 6002045.19 560179.85 5520.09 0.00 0.00 MWD+IFR+MS 8300.00 90.00 225.00 3927.00 3855.00 6001973.87 560109.77 5587.60 0.00 0.00 MWD+IFR+MS 8400.00 90.00 225.00 3927.00 3855.00 6001902.55 560039.69 5655.12 0.00 0.00 MWD+IFR+MS 8500.00 90.00 225.00 3927.00 3855.00 6001831.22 559969.61 5722.63 0.00 0.00 MWD+IFR+MS 8600.00 90.00 225.00 3927.00 3855.00 6001759.90 559899.53 5790.15 0.00 0.00 MWD+IFR+MS 8700.00 90.00 225.00 3927.00 3855.00 6001688.58 559829.45 5857.66 0.00 0.00 MWD+IFR+MS 8800.00 90.00 225.00 3927.00 3855.00 6001617.26 559759.37 5925.18 0.00 0.00 MWD+IFR+MS 8871.87 90.00 225.00 3927.00 3855.00 6001566.00 559709.00 5973.70 0.00 0.00 MPS-08 T3 8900.00 90.35 223.93 3926.91 3854.91 6001545.75 559689.48 5992.49 4.00 287.93 MWD+IFR+MS 8978.10 91.31 220.96 3925.79 3853.79 6001487.68 559637.30 6042.59 4.00 287.92 MWD+IFR+MS 9000.00 91.31 220.96 3925.29 3853.29 6001471.02 559623.09 6056.19 0.00 0.00 MWD+IFR+MS 9100.00 91.31 220.96 3923.01 3851.01 6001394.95 559558.23 6118.32 0.00 0.00 MWD+IFR+MS 9200.00 91.31 220.96 3920.73 3848.73 6001318.88 559493.37 6180.45 0.00 0.00 MWD+IFR+MS 9300.00 91.31 220.96 3918.45 3846.45 6001242.82 559428.51 6242.58 0.00 0.00 MWD+IFR+MS 9400.00 91.31 220.96 3916.17 3844.17 6001166.75 559363.65 6304.71 0.00 0.00 MWD+IFR+MS 9500.00 91.31 220.96 3913.89 3841.89 6001090.68 559298.79 6366.84 0.00 0.00 MWD+IFR+MS , Ltómpahy: BPAmoco ¡¡Field: Milne Point ;§i~~: M Pt SPad , ":w~n: .,' Plan MPSM32i 'f",~np~~h: Plan MÞSM32i Survey MD Inèi Azim ff deg deg 9528.62 91.31 220.96 9577.76 91.57 219.01 9600.00 91.57 219.01 9700.00 91.57 219.01 9800.00 91.57 219.01 9900.00 91.57 219.01 10000.00 91.57 219.01 10100.00 91.57 219.01 10200.00 91.57 219.01 10300.00 91.57 219.01 10400.00 91.57 219.01 10500.00 91.57 219.01 10600.00 91.57 219.01 10672.12 91.57 219.01 ) ) BP KW A Planning Report MAP Datë:: ,'1/22/2003' ,', ::{I Time:' 1 ~:19:03 ", : . ': . Ita~~:' 'Ço~~r.dil1ªte(NEJReferenc~: , :,Well::Plary';¥PSf32I,'!:Irµe North)' , yertJcaU1VD)Rèfert1nc!:;.?$MPac:l,Dey>72.0 ,">, ::;w , ,§e~t\()n (~T;S) Re!~rence:;·:."Well\(p.09N,Q.09E,~!?;~3~i) .¡,>: '"..' ',~urvey ¢.àlculati~Wn Meth()~:MinlmumGurva1iJre:'~ .:, . Pb:';Oràcle Sy.s "slMapN ~apE.; YS ":>tDÛ~ TFO.. ToôllCôhllnent >/:, ft ft <ft "'/{':deg/100ft,; deg 3841.23 6001068.91 559280.23 6384.62 0.00 0.00 MWD+IFR+MS 3912.00 3840.00 6001031.00 559249.00 6414.49 4.00 277.72 MPS-08 T 4 3911.39 3839.39 6001013.60 559235.16 6427.70 0.00 0.00 MWD+IFR+MS 3908.65 3836.65 6000935.39 559172.94 6487.12 0.00 0.00 MWD+IFR+MS 3905.91 3833.91 6000857.17 559110.71 6546.54 0.00 0.00 MWD+IFR+MS 3903.17 3831.17 6000778.95 559048.48 6605.97 0.00 0.00 MWD+IFR+MS 3900.43 3828.43 6000700.73 558986.25 6665.39 0.00 0.00 MWD+IFR+MS 3897.69 3825.69 6000622.51 558924.02 6724.81 0.00 0.00 MWD+IFR+MS 3894.95 3822.95 6000544.29 558861.79 6784.23 0.00 0.00 MWD+IFR+MS 3892.21 3820.21 6000466.07 558799.57 6843.66 0.00 0.00 MWD+IFR+MS 3889.47 3817.47 6000387.85 558737.34 6903.08 0.00 0.00 MWD+IFR+MS 3886.73 3814.73 6000309.63 558675.11 6962.50 0.00 0.00 MWD+IFR+MS 3883.99 3811.99 6000231.41 558612.88 7021.92 0.00 0.00 MWD+IFR+MS 3882.00 3810.00 6000175.00 558568.00 7064.78 0.00 0.00 MPS-08 T5 ) ) p 055059 DATE 4/4/2003 CHECK NO. ObbOb9 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT NET ~/4/2003 INV# CK0401031 PERMIT TO DRILL FEE \)'fS' 3?-. RECEIVED MAY 1 5 1.003 A\aska Oi\ & Gas Cons. Commission Anchorag1 E ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHQ~AGE, AK,995J 13-6612 PAY: NATIONAL CITY BANK Ashland. Ohio 56-389 412 No. P 055059 CONSOLIDATED COMMERCIAL ACCOUNT 8. ",i~MbuNT TO THE ORDER OF: :::::, .",,""','. ;"':," '.:'. " . '.:::' . ..: ','.. , " " ,.' " ,,: " ,',' . c,' "'.<. :" . ".::,' ,:, ': '" ':. ';. :,'.-,:,,::' ", "';',' ',"" ",,' ;"" ',',',', ',', ,,',,"',' ",,'" ,',',' ÄLA§KA ()IL ~G~S GRNSERV&TIO~ CqMtv1IS$IO[,\J> 333 W 7TH AVENUE "", SUITE 10Pi\ ANCHORAGE/AK 99501-3539 ***t~~*$1 00.00******* NÓTVALlDÅFTER 120 DAYS ~,:,\~:~:,~~,>::::~~:::?",:::..:::~~~g::{r,t,",' ~;;:'~?;::~~:~_~~}~;~,;,~_,}~{T ::":'.:::',' lI~r<l!'·'··"" ",'.,:«:..:;...:....... ::'.' ~~. .:....:. ...-:¡.. ~" æ3~...,,,,,,~.."",""1 _II -",. I.: ~: ~ /: ~:,~::: ::;:.:~':': :i~.···.····· .:~;~:·:1f:§~t ;·:~~·~:~t~f~:·:~:·~ ;~:\ ::; .:~':~: ~~'j III 0 5 5 0 5 9 III I: 0 ~ ~ 2 0 ~ B 9 5 I: 0 ~ 2 7 a 9 b III ) ) TRANSMITAL LETTER CHECKLIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER "rnPu- ~ -32- ;;z.o3 - oCf' 2-- WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (H API number last two (2) digits are between 60-69) "CLUE" The permit is for a new wellboresegment of existing well Permit No, API No. Production. should continue to be reported as a function' of the original API number. stated above. BOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/1 0/02 C\jody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to the spacing . exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below tbe permafrost or from where samples are first caught and 10' sample intervals through target zones. .~~~ç:·~Ë~!Yt!J;.sI-lÊP~!-.I~!:, Company BP EXPL.QRATION (ALASKA) INC Well Name: MILNE POINT UNIT SB S-32 Program 'pEV Well bore seg D PTD#: 2030920 Field & Pool ~lL.NEE..OJbIT,...s~I::LI3AQ.EILBLFF OJkß25JA..o Initial ClasslType -DE~1L- GeoArea .890 Unit 11328 On/Off Shore 0.11..- Annular Disposal D Administration 1 P!3(mitfe~ attacheØ. . . . . _ _ . . . . . . ... ................... _ . . . . . . . . . Y!3$ . . . . . _ . _ _ . . . . . . _ . . . . . . . . . . . . . . . . . _ . . . . . _ . . _ _ _ _ _ . . . _ . . . . . _ . _ _ . _ . . . . . . . .. . . . . . 2 .Leas!3 .numb~r apPJop.riat!3. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ _ _ _ . _ . . . . . Y!3S . . _ . . . . . . _ _ _ .. _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . _ _ . . . . . . . _ . . . . . . _ . . . . . . .. . . . 3 .U.niJ:lU~ well.n.alJl!3 .aod Iwmb.ß( _ _ _ _ _ _ . _ . . . . . . . . . _ . . . . . . . . _ _ _ _ . . . . . . . . .Y!3$ . . . _ . . _ _ . . . . _ . . . . . . . . . . _ . . . _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ . _ . . _ . _ _ _ _ _ _ _ _ _ . _ _ _ . _ _ _ 4 WeJI Jo.cat!3d in.a.d.efineØ .pool_ . . . . . . _ . . _ _ _ _ . . _ .. _ . . _ _ _ _ . _ _ . . _ _ . _ . . . _ . Y!3s . . _ _ . . _ . _ _ . _ . . . . . . . . . . . . .. . . .. _ _ _ _ _ . . . . . . . . _ _ .. .. . . _ . . . . _ . . _ _ . . .. - . . . . . . . . . . . . . . 5 WeJI Jo.cat!3d prop~r di.slance.from drilling unitb.ounda(y _ . _ . . . . _ . _ _ _ _ _ _ . _ _ _ _ . _ . _ Yes _ . . . . . . . . . . . . _ . . _ . . _ _ . . . . . . . . . . . _ _ _ _ _ _ . . . . . . . . .. _ .. _ _ . _ . . . . . . _ _ - _ _ .. . . . _ . . _ . . _ 6 WeJI Jo_cat!3d prop~r di.stance. from Qther wells_ _ _ _ _ _ _ . . . . _ _ . . . _ . _ . _ . . _ _ _ _ _ _ _ Y!3$ _ _ _ _ _ . _ . . . . . . . . _ . . . . . . .. . . . _ _ _ _ _ . _ . . . . . . . _ . .. . . _ . . . . . . _ . _ _ . . . . . . . . . . . _ . . _ . . . . 7 .Sufficient acreag.ß.ayailable tn.drilJirm unit _ .. . _ . _ _ _ . _ . _ _ _ .. . _ .. _ _ . . . . . . _ . _ . . . Yes. . _ _ _ . . . . _ _ _ . . . . . _ . . . _ . _ _ _ _ _ . . _ . _ _ . _ . . _ _ _ _ _ . . _ . . . . . . _ _ _ _ . . . . . _ . .. . . . _ . .. 8 Jf_d~viated, js_weJlboJ~ platJl1cluped. _ _ _ _ _ ~ _ _ _ _ .. _ _ _ _ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _y~s _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ M _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .. _ _ _ _ _ 9 .o.perator onN affected p~rty. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ . _ _ . _ . _ _ Y!3S . _ . . . . . . _ . . _ . .. _ .. .. . _ _ . . . . . . . . . . _ . _ _ _ _ _ . . . . . . . _ _ _ _ _ _ .. . . . . . . . _ _ _ .. . _ .. . . _ . . . . . . _ 10 .o.perator h~s.approprLate.b.ond in JQrce_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . . . . _ _ . _ Y!3$ _ _ _ _ _ _ _ _ . . . . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 11 P!3mlitcao Þe i.ssu.ed witho_ut con$~l'\(atiQn Qrd~r. _ . . . _ . . . . . . . . . _ _ _ _ _ _ _ . . . . . . Y!3$ . . . _ _ . . . _ _ _ .. _ _ _ _ . . . . . . . . . . . . . . _ _ _ _ . _ . . . . . _ . . _ _ _ . _ _ . . . . . . . . . _ . _ _ . _ - - - - _ - _ .. - _ Appr Date 12 P!3Unitcao Þe i.ssu.ed witho_ut admini~tr.ativ.e.apprO\laJ . . . . _ . . . . . . . . . _ . . _ . . . _ . .. . Yes _ . . . . . . . . . . . . . . _ _ . _ _ _ . . . . . . . . . . . . _ _ . _ .. - . . . . . . . . . - - . - . . . . . . . . . .. . - - - .. - . - - . - . . sr- 5/19/2003 13 Can permit be approved before 15-day wait Yes ) 14 WeJIJQcat!3dwithJnareaan.d.strataauthQri,zedby.lojectioIJOrd!3(~(puUO#in.comlJl!3ots).(F.or_ NA............ _ _.. _ _.... _........... _ _ _ _ _ _ _ _ _ _ _ _ _.. _.. _ _ _ _. _ _. _... _ _ _ _ _ _ _. _ -_ 15 All wells_Vt{ithin .1 £4 _mil.ß _arena_of (eyiew id!3otified (FO( s.ervic!3 W.ßIJ Qnly:). _ _ _ _ _ _ _ _ _ _ _ _ . _ NA . _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . . . _ . _ _ _ _ _ _ _ _ . _ _ _ . . . . . _ _ _ _ _ _ _ _ . . . . . _ _ _ _ _ _ _ _ _ _ . . _ . _ . _ . 16 Pre_-produçecl. injector; øuratJo.n.of pre-p(oØuction l!3ss.than.3. months_(F.or.seryiçe welt Qn!y) . _ NA . _ _ _ . _ _ . . .. . . . . . . .. . _ . _ _ _ _ _ _ _ _ . . . _ . . . . _ _ _ . _ . _ _ . . . . . . . . . _ _ _ . . . . . . . . . - . . - . . - - - . 17 ACMP.FJndlng .of CQn.sisteocy_haS b~enJs.s!J~d.fQrJhis project. . _ _ _ _ _ . . _ . . . _ . . . . . . NA . . _ _ . _ . . . . . _ . _ _ . . . . . . _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ .. _ _ _ _ _ _ . _ _ . . _ .. _ . _ _ - - - - - - - . . - . . - - 18 .C.ooduçto( str:.in.9.prQvided _ _ . . _ _ . _ . _ _ . . . _ _ _ _ _ . _ _ .. _ . _ . . . _ . _ _ _ . .. . . . . . Y!3S _ .. . . _ _ . . . . . . . . _ . . . . . . _ . . _ . _ . _ _ _ . . . . . . . . . . _ . _ _ _ _ . . . . . . _ . . _ _ _ _ . _ _ . _ . . . . . . . . . . 19 _Sur:fac!3.casJng_prQtects.aJl.known.USDW~................. _ _. _...... _ _... NA....... .Allaquiferse)œmpt!3c14QCER147>t02.(b).(3.).. _.. _ _. _ _ _ _ _.... _ _ _ _ _ _ _ _ _.......... _.... 20 _CMTvol.a.dequ.ate.to Ci(cIJlate.on _cQnduçtor.& $u.rf.csg . . . . . . . . . _ . . _ _ . _ . . _ _ . _ _ . Y!3$ . . . . . . . . . . . . . _ . _ . . _ _ . . . . . . . . . . . . . . _ _ _ _ _ _ . . . . . . . . . . _ . _ _ . . . . . . . . . . _ _ _ _ . - _ - .. _ .. 21 .CMTvol. a.dequ.ate.tQ ti~-i.n JQng .string to .sur:f csg. . . . . . . . . . . _ . . . . . . . . . . _ . _ . _ . No _ _ _ . _ _ . . . . . . . _ . . . . _ _ _ _ . . . _ . _ . . . _ . . . . . . _ . . . _ . _ . . . . . _ _ . . _ . . . . . . . .. . .. . . . _ _ _ . _ _ _ _ 22 .GMT. Vt{ill coyer .all known .productiye hOJilQn.s. . _ . . _ _ . . . . . . . . . . . . . . . . . . . . . . . N.o _ . . . _ _ _ _ Slotted Jio~r p!.anned c . . . . _ _ _ _ _ _ _ _ _ _ . _ . . . . . _ _ _ . _ _ _ _ _ _ _ _ . . . . . . . . _ _ . _ _ _ _ _ . . . _ . . 23 .Gasiog de.si.9O~ ad.equa.t~ fo( C,T, B .&.p.erl1J~frost . . . . . . . . . . . . . . . . . . . . _ _ . _ . _ Y!3S _ . . . . . . _ . . _ . . _ . . . . _ . _ _ _ _ _ . . _ . . . . . . . . _ . . _ _ _ _ . . . . _ . . . . . _ . _ _ . - . . . . . . . .. . . . . . .. - . 24 AOequate.tan!<age.orre.serve pit. _ . . . . . . . . . . . . . . . . . . . . _ . . . . . . . _ . _ . _ _ . Y!3S _ _ _ . _ . . B.ig !3qUiRP!3d with. steeJ pits, No r~S!3(Ve plaon.ed.. W_aste tQ G&I, _ _ _ . . . . _ _ . . _ _ . . _ . . . _ . .. . _ _ . . . _ 25 JLa_re-or:.ilt has_a_ tO~4_03 for aba_ndQnment be!3O apprQved _ _ _ _ _ _ . _ . _ . _ _ _ . _ _ . . . _ _ NA. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . . . . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ . . . . . . . . . . . . _ . _ _ . . . _ _ . _ . _ _ - _ - . - . .. . _ - 26 AØequate .we 1.1 bore. $.eparation proPQ$.eø. . . . . . . . . . . . . . . . . _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ Y!3$ _ _ _ _ . _ . ~Q çlQs_e .approacl1 jd.entjfi!3d. _ I?r9~imety S3oaJy-si.s P!3r:fQrmed. _ _ _ _ . . . . . _ _ . . _ _ . _ _ . _ _ . . . . _ . _ . . . . 27 n_diverj~r r~quire.d clo_es it m.eet.reguJa_tions_ _ _ . _ . _ _ . _ . _ _ _ _ . . . _ . . . _ . . _ . . . . _ Y~s . . . . _ _ . . _ _ _ _ _ _ _ . _ _ _ . . . _ . _ . _ _ . _ _ _ _ _ _ _ . _ . . . _ . . _ . . _ _ _ _ . . _ _ . . . . . . _ _ _ . . . _ _ _ _ . . . . 28 DriIJiog fluid_program schematic.&. ~quip Jistadequat!3. . . . . . . . _ . _ . . . . . . _ _ _ _ _ _ _ _ Y!3S _ _ _ _ _ _ . Maximum anticipated BHP,.8.35EMW.. .PJa.nned_ MW, 9.0 ~ 9.3 intermediate. _ 8.6 -: to_.o. prod.uctionc _ . . . _ _ . . _ 29 _BOP!::s..do .they m.eetreguJation . . . . . _ _ _ . . _ . . . . . . . . . _ . . . . .. . . . _ _ _ . _ _ _ Y!3S _ _ _ _ _ _ . . . . _ . . . _ . . . . . . . . _ _ _ . _ _ . _ . _ . . . . . . . _ . _ . . _ _ _ _ _ _ _ . . . . _ _ _ _ . _ . . _ . _ . . . _ . . 30 .BOPE.pre_s$ ratiog app(op(ia.te; t~st to .(put p~ig in _comments) _ . . . . . _ . . . . . . . . . . _ . _ Y!3$ _ _ _ _ _ . _ MASP e$timated at t678 p~i._ BP plaos. to te_st. to 35QO.p.si. . . . _ _ _ _ _ . . . _ _ _ . _ _ _ _ _ _ _ _ _ _ . . _ 31 .Gl1oke.manifQld cQmpJies_ w/APLRR-53_ (May 84). _ _ _ _ _ _ _ . _ . . . . . . . . _ _ _ . . . _ _ _ . Y!3$ . . . . . . . . _ _ . . _ . . _ . . . . . _ . . _ . _ _ _ . _ . _ _ _ . . _ . _ _ . _ _ _ _ . . _ _ _ _ . _ _ _ _ . . . . . _ - _ _ 32 Work will OCCU( withoutoperation _sbutdown _ _ _ . . . _ . _ _ _ _ . . _ . . _ _ . _ _ _ . _ _ _ _ _ . _ Y!3S . . . . . . . . . . . . _ _ . . _ . _ _ _ _ . _ . . . . . . . _ . . . . . . .. . _ _ _ _ _ _ _ . . . . . . . . _ . . _ . _ . . . . . _ . _ _ . _ . . _ 33 Js_ pres_ence. oJ H2S gas. prQb_able _ _ . . _ _ _ . . . . . _ _ . . _ _ _ . . . . _ _ . . _ . _ _ _ . . No _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. .... _ _ . _ _ _ _ _ _ . . _ . . _ . . . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ - . . - - _ _ - - 34 Mechani.caLcondjti.on of. weJI$ withJn AQR y~rified.cFor.s.ß(Vice w!311 QnJYL . . . _ _ . _ . _ _ . .. _ NA _ . . . . _ . . . . . _ _ . _ _ _ _ . _ . _ _ _ . . . _ _ . _ _ . _ _ . . . . _ _ _ _ _ . . _ _ . _ _ . . . _ . - - - . - . - - - Engineering Appr Date Tt:M 5/20/2003 ) Geology Appr SFD Date 5/19/2003 35 P!3(mit.cao be i~su.ed wlo. hydr.og~n.s.uIJid~ meaSI,Jr:.es. _ . _ _ . . _ . _ _ _ . . . Y!3S _ _ _ _ _ _ _ _ _ _ .. _ . . . . . . . . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ . . . _ _ _ _ 36 .Data_pre.sented Qn_ potentia.! P\leJRres.Sl,lr!3 ~on.es . ... _ _ _ _ . _ . . . _ _ _ _ Y!3S _ _ _ . _ . _ Expected. pres.sur!3.in. NS (eservQir.saod. is 8..35 ppg EMW, . . . . . _ _ _ _ . _ . 37 $eismi.c.analys_is.oJ sha.llow gas_zolJ~s. _ . _ _ _ . _ . . . . . _ . _ .. . . _ _ . _ _ . _ . . _ _ . . _ _ NA _ . . _ _ _ _ . . _ . _ . . . . . . . . _ . _ _ _ . _ _ _ _ _ _ _ _ . _ _ _ . _ . _ . _ . _ _ . _ _ _ _ . . . . . . . . 38 _S!3abed çonditiPIJ suwey (if Qff-~hpr:.e) _ _ _ . _ _ . _ .. . _ _ . _ . . . . . . . . . _ . . . . _ _ NA. . . . . . _ . . . . _ _ _ . . _ _ .. _ _ _ _ _ _ _ _ _ _ _ . _ _ . . _ _ _ _ . _ _ _ _ _ . _ _ _ . . . . . _ _ . . . . . _ _ _ . . . . . .. 39 . Co.ntaçt narn.ß~phQn.e .fQr .weekly progress .reports [e~ploratory .0nlYl _ _ _ . . . _ . . . . _ NA_ _ _ _ _ _ . _ _ _ _ _ . _ . _ . _ . _ _ . _ _ . _ _ _ _ . _ _ _ . _ . _ _ . _ _ _ _ . . .. . _ . _ _ _ _ . . _ _ . . . . . . . _ . . _ _ . . " ~ - - . - - . . Geologic c;;m~ioner: Date: vV) O§jZ7/&J Engineering ¡¿Sianer. ;ff Public commissione~ ~~ Date Schrader Bluff NB horizontal producer. , ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennilling Process but is part of the history file. To improve the readability of the Well History file and to sim.plify finding information, information of this nature is accumulated at the end of the file under APPEN.DIX. No special effort has been made to chronologically organize this category of information. ( Sperry-Sun Dri~ling Services LIS Scan Utility t' ( (J03-09 ~ -=ff I '8l{~ $Revision: 3 $ LisLib $Revision: 4 $ Thu Aug 28 09:32:31 2003 Reel Header Service name.... . . . . . . . . .LISTPE Date. . . . .. . . . . . . . . . .. .. ..03/08/28 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/08/28 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name. . . . . . .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPS-32 500292315700 B.P.Exploration (Alaska) Inc. Sperry-Sun Drilling Services 28-AUG-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW2500145 R. FRENCH C. DIXON MWD RUN 2 AK-MW2500145 J. STRAHAN C. DIXON MWD RUN 3 AK-MW2500145 J. STRAHAN C. DIXON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 12 12N 10E 3259 383 71.97 38.10 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 13.500 9.875 6.125 CASING SIZE (IN) 20.000 10.750 7.625 DRILLERS DEPTH (FT) 112.0 3173.0 7543.0 RECEIVED AUG 29 2003 # Rß~\\~~ ~~ Alaska 0i1 & Gas Cons. Commisskm Anchcnge REMARKS: ( (. 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1 - 3 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. MWD RUNS 2 & 3 ALSO INCLUDED ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 4. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM D. SCHNORR, BP ALASKA, INC., DATED 8/22/03. MWD DATA ARE CONSIDERED PDC. 5. MWD RUNS 1 - 3 REPRESENT WELL MPS-32 WITH API#: 50-029-23157-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10679'MD/3876'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name............ .STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/08/28 Maximum Physical Record. .65535 File Type.. ~........... ..LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 67.5 113.5 3160.5 3160.5 3160.5 3160.5 3160.5 STOP DEPTH 10626.0 10679.0 10633.0 10633.0 10633.0 10633.0 10633.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ ( ,(. # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ BIT RUN NO 1 2 3 MERGE TOP 67.5 3180.0 7555.0 MERGE BASE 3180.0 7555.0 10679.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type... ..0 Logging Direction................ . Down Optical log depth units... ...... ..Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record........ . . . . .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 67.5 10679 5373.25 21224 67.5 10679 ROP MWD FT/H 0.14 2762.86 288.033 21132 113.5 10679 GR MWD API 9.51 135.91 64.101 21118 67.5 10626 RPX MWD OHMM 0.16 1608.83 24.7074 14946 3160.5 10633 RPS MWD OHMM 0.19 2000 39.0954 14946 3160.5 10633 RPM MWD OHMM 0.22 2000 52.9472 14946 3160.5 10633 RPD MWD OHMM 0.1 2000 76.3841 14946 3160.5 10633 FET MWD HOUR 0.06 45.96 0.909419 14946 3160.5 10633 First Reading For Entire File......... .67.5 Last Reading For Entire File.......... .10679 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/08/28 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... ( Version Number.......... .~.O.O Date of Generation...... .03/08/28 Maximum Physical Record. .65535 F i 1 e Typ e. . . . . . . . . . . . . . . . LO Previous File Name. ..... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 f header data for each bit run in separate files. 1 .5000 START DEPTH 67.5 113.5 STOP DEPTH 3135.0 3180.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record 19-JUN-03 Insite 66.37 Memory 3180.0 112.0 3180.0 .0 72.6 TOOL NUMBER 124725 13.500 112.0 Water 9.40 200.0 8.5 500 10.0 Based .000 .000 .000 .000 .0 64.4 .0 .0 I ( Data Record Type........:.........O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point........... ...Undefined Frame Spacing..................... 60 .1IN Max frames per record........ ... ..Undefined Absent value... ........... ....... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O (' Name Service Order DEPT ROP MWD010 GR MWD010 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 67.5 3180 1623.75 6226 67.5 3180 ROP MWD010 FT/H 63.17 855.12 270.256 6134 113.5 3180 GR MWD010 API 20.01 135.91 65.4795 6136 67.5 3135 First Reading For Entire File......... .67.5 Last Reading For Entire File.......... .3180 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/08/28 Maximum Physical Record. .65535 File Type...... . . . . . . . . . . LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/08/28 Maximum Physical Record..65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPX RPS ROP 3 header data for each bit run in separate files. 2 .5000 START DEPTH 3135.5 3160.5 3160.5 3160.5 3160.5 3160.5 3180.5 STOP DEPTH 7516.0 7508.5 7508.5 7508.5 7508.5 7508.5 7555.0 $ ( # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.......... ........0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units... ....... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O (' 22-JUN-03 Insite 66.37 Memory 7555.0 3180.0 7555.0 67.7 72.5 TOOL NUMBER 142827 102982 9.875 3173.0 LSND 9.30 50.0 8.5 200 5.0 8.000 4.990 9.000 5.000 62.0 103.4 62.0 62.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM RPD FET It 4 4 4 MWD020 MWD020 MWD020 OHMM OHMM HOUR 1 1 1 68 68 68 f 6 7 8 20 24 28 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3135.5 7555 5345.25 8840 3135.5 7555 ROP MWD020 FT/H 2.14 2762.86 396.658 8750 3180.5 7555 GR MWD020 API 9.51 120.43 66.1181 8762 3135.5 7516 RPX MWD020 OHMM 2.99 431.97 20.6785 8697 3160.5 7508.5 RPS MWD020 OHMM 1.52 2000 20.3959 8697 3160.5 7508.5 RPM MWD020 OHMM 0.34 2000 24.201 8697 3160.5 7508.5 RPD MWD020 OHMM 0.15 2000 26.0325 8697 3160.5 7508.5 FET MWD020 HOUR 0.06 35.67 0.561703 8697 3160.5 7508.5 First Reading For Entire File......... .3135.5 Last Reading For Entire File.......... .7555 File Trailer Service name.......... ...STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/08/28 Maximum Physical Record. .65535 File Type................ LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/08/28 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 7509.0 7509.0 7509.0 7509.0 7509.0 7516.5 7555.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: STOP DEPTH 10633.0 10633.0 10633.0 10633.0 10633.0 10626.0 10679.0 26-JUN-03 Insite 66.37 DAT~ TYPE (MEMORY OR REAt TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: l'IME) : # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type... ..0 Logging Direction...... .......... . Down Optical log depth units.... ...... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record........... ..Undefined Absent value.. . . . . . . . . . . . . . . . . . . . . -999 Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Memory 10679.0 7555.0 10679.0 72.8 95.9 TOOL NUMBER 65036 148574 6.125 7543.0 FLO PRO 9.60 56.0 9.0 54000 3.5 .030 .020 .080 .080 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 ( 65.0 95.1 65.0 65.0 First Last / End Of LIS File Physical EOF Physical EOF Reel Trailer Service name. ........... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/08/28 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.............. ..UNKNOWN Continuation Number..... .01 Next Reel Name......... ..UNKNOWN Comments............... ..STS LIS Writing Library. Scientific Technical Services Tape Trailer Service name...... ...... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/08/28 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.............. ..UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments.......... ...... .STS LIS Writing Library. Scientific Technical Services Physical EOF File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.. .... .03/08/28 Maximum Physical Record. .65535 File Type................ LO Next File Name.......... ,STSLIB,005 First Reading For Entire File,..... ....7509 Last Reading For Entire File.......... .10679 Name Service Unit M' ( Max Mean Nsam ( ~,-eading Reading In DEPT FT 7509 10679 9094 6341 7509 10679 ROP MWD030 FT/H 0.14 814.65 153.362 6248 7555,5 10679 GR MWD030 API 26.07 107.49 59.8995 6220 7516.5 10626 RPX MWD030 OHMM 0.16 1608.83 30.3146 6249 7509 10633 RPS MWD030 OHMM 0.19 2000 65.1204 6249 7509 10633 RPM MWD030 OHMM 0.22 2000 92.9544 6249 7509 10633 RPD MWD030 OHMM 0.1 2000 146.461 6249 7509 10633 FET MWD030 HOUR 0.2 45.96 1.39335 6249 7509 10633